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Home My WebLink About195-159XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. / ~.~"~'/5'~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: ~ianna Vincent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: /s/ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Plug~lEa~..~f~r4i~r~ck~ WELL COMPLETION OR REOOMPLETION REPORT AND LOG 1. Status of Well Classification of Service ~ell 1--] Oil [--~ Gas E~ Suspended [~] Abandoned ~] Service ........ m, ~ ~o n.r, ne P~ml 2. Name of Operator 7. Permit Numb'~i='''"''-''' ...... BP Exploration (Alaska)Inc. 95-159 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 _,~.____ 50-029-22607 4. Location of well at surface 1~;2~1'i¢~46; 9. Unit or Lease Name 2234' NSL, 3301' WEL, SEC. 28, T13N, R10E, UM - : ! '~I¢~~.~~. Milne Point Unit At top of productive interval ~.~,,~, . 10. Well Number N/A MPJ-19 At total depth ., 11. Field and Pool 2395' NSL, 1159' WEL, SEC. 19, T13N, R10E, UM -~ Milne Point Unit / Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Sands KBE -- 65.6'I ADL 025515 12. Date Spudded10/16/95 113' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'115' water depth' if °ffsh°re 16' N°' °f C°mpleti°nsl 0/24/95 10/27/95 N/A MSL Zero 17. Total Depth (MD+TVD)13087 7155 FT,I18' Plug Back Depth (MD+TVD)I19' Directi°nal Survey 120' Depth where seeM set 121' Thickness °f Permafr°st3795 2910 FTI [~Yes I~No N/A MD 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, Gyro, CDN, CDR 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 32' 112' 24" __.50 sx Arcticset I (Approx.) 9-5/8" 40# L-80 31' 3391' 12-1/4" 874 sx PF 'E', 250 sx 'G', 150 sx PF 'E' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None N/A MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12590'-13080' Cement plug, 250 sx Class 'G' 5490'-6390' P&A Cement plug, 400 sx Class 'G' 4500'-5450' P&A Cement plug, 400 sx Class 'G' 3600'-4290' Kick-off plug, 275 sx Class 'G' 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Not on Production I N/A Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-BBL CHOKE SIZE IGAs-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-DEL GAS-MCF WATER-DEL OIL GRAWTY-API (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. lissio Form 10-407 Rev. 07-01-80 Submit In Duplicate Geologic Markers i30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. (Subsea) TKUP 12596' 6730' TKUC 12737' 6833' TKUB 12803' 6881' TKAZ 13000' 7026' RECEIVED DEC '1 ,_5 199 ' Alaska 0il & Gas Cons. 00remission Anchorage 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,///'~ L/~ ~L/~(~ ~,,' ,4/. ,' ~///'~_//'(/'~7 ChipAIvo?d / ~67/~ (~.'-/U,,¢.~,/-//J/¢V-¢~ Title 8-en~,,Jor ........ v Englr'~a¢-'-7-'/7z_~' Date / MPJ-19 95-159 95-186 Prepared By Name/Number: Kathy Campoamor, 564-5122 Well Number Permit No,/Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Qther-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ~P/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: MPJ-19 BOROUGH: NORTH SLOPE UNIT: UNKNOWN FIELD: UNKNOWN LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 10/15/95 06:00 SPUD: RELEASE: 10/30/95 12:00 OPERATION: DRLG RIG: NABORS ~ 10/15/95 ( 1) TD: 112'( 0) 10/16/95 (2) TD: 112' ( 0) 10/17/95 ( 3) TD: 2297' (2185) 10/18/95 ( 4) TD: 3421' (1124) 10/19/95 (5) TD: 3421' ( 0) 10/20/95 (6) TD: 5548' (2127) AlasKaOit&_. GasCorm. Co~timi~iOR MOVING SUB MW: 0.0 VIS: ~ncnorage INSTALL NEW FLUID END ON MUD PUMP. BLOW DOWN & MOVE SUB F/I-PAD T/J-PAD. PU BHA MW: 0.0 VIS: 0 MIRU. RIG ACCEPTED @ 1800 HRS., 10/15/95 MPJ-19. NU DIVERTER SYSTEM, CHANGING OUT FLUID END & DISCHARGE MANIFOLD ON PUMP, MODIFY PITCHER NIPPLE & NU FLOWLINE. MIX MUD. PU TOOLS & CLEAN RIG. PU HWDP & DP. DRILLING MW: 0.0 VIS: 0 FUNCTION TEST DIVERTER. MU BIT, CHANGE MOTOR. PU BHA, SURFACE CHECK MUD SYSTEM. ATTEMPT TO SPUD, FLOWLINE PLUGGED WITH SACKS FROM CONDUCTOR. DRILL F/l12' T/1154'. SHORT TRIP. OK. DRILL F/1154' T. 2201'. CBU, MONITOR WELL. SHORT TRIP. OK. DRILL F/2201 T/2297' CEMENTING SURFACE CASING MW: 0.0 VIS: 0 DRILL F/2297' T/3420'. CIRC HI-LOW SWEEP AROUND, MONITOR FLOW, PUMP PILL. POOH T/JARS. RIH TAG BRIDGE. CIRC & MONITOR WELL. POOH, LD BHA. OK. PU CASING TOOL, RU INJECTION LINE TO J-13. RIH 9-5/8", SHOE @ 3390'. RU CEMENTING HEAD. CIRC. CEMENTING. PU BHA %2 MW: 0.0 VIS: 0 CEMENT JOB, TEST LINES, DROPPED TOP PLUG, BLED OFF FLOATS. OK. LD LANDING JT AND ND DIVERTER SYSTEM. RU & PUMP TOP JOB. RD HALLIBURTON. NU GEN V WELLHEAD & TEST. NU BOPE. CHANGE OUT BAILS. INSTALL TEST PLUG & TESP BOPE. BOBBY FOSTER WITH AOGCC WAIVED WITNESSING TEST. ONE CHOKE VALVE FAILED & BOTH IBOP FAILED. REPAIR CHOKE VALVE & BOTH IBOP VALVES. RETEST VALVES, PULL TEST PLUG & INSTALL WEAR RING. PU BHA #2. PU BIT, MOTOR & ORIENT MWD. LOAD LWD TOOLS. TIH MW: 0.0 VIS: 0 FINISH MU BHA #2. TIH TO FLOAT COLLAR. PU DP. TEST CASING. OK. DRILL FLOAT COLLAR, CEMENT, FLOAT SHOE & 10' NEW FORMATION T/3430' CIRC HOLE CLEAN. DRILL 8-1/2" HOLE F/3430' T/5548'. CBU. MONITOR WELL & PUMP PILL. SHORT TRIP TO CASING SHOE. OK. SERVICE TOP DRIVE & CHANGE OUT BAILS. TIH & PU DP. ,fELL : MPJ-19 OPERATION: RIG : NABORS 22E PAGE: 2 10/21/95 ( 7) TD: 7649' (2101) 10/22/95 (8) TD: 9935' (2286) 10/23/95 (9) TD:l1550' (1615) 10/24/95 (10) TD:12960' (1410) 10/25/95 (11) TD:13087' ( 127) 10/26/95 (12) TD:13087' ( 0) 10/27/95 (13) TD:13087' ( 0) DRILLING 8-1/2" HOLE MW: 0.0 VIS: 0 FINISH TIH. NO HOLE FILL. RU ATLAS & GYRODATA. RUN GYRO F/5200' T/3200'. CHANGE BAILS. DRILL & SURVEY 8-1/2" HOLE F/5548' T/7649' DRILLING 8-1/2" HOLE MW: 0.0 VIS: 0 DRILL & SURVEY 8-1/2" HOLE F/7649' T/8506'. FINISH PUMPING HI-LO SWEEP AROUND & MONITOR WELL. SHORT TRIP T/5500'_ OK. PU DP & TIH. OK. DRILL & SURVEY 8-1/2" HOLE F/8506' T/9935' DRILLING 8-1/2" HOLE MW: 0.0 VIS: 0 DRILL & SURVEY 8-1/2" HOLE F/9935' T/11267'. CIRC SWEEP AROUND. MONITOR WELL & PUMP PILL. POOH TO CASING SHOE. WORK THRU TIGHT SPOTS, SLIP & CUT DRILLING LINE, SERVICE TOP DRIVE. TIH. OK. REAM LAST STAND TO BOTTOM. NO FILL. DRILL & SURVEY 8-1/2" HOLE F/11267' T/11550' DRILLING 8-1/2" HOLE MW: 0.0 VIS: 0 DRILL & SURVEY 8-1/2" HOLE F/11550' T/12495'. FINISH CIRC SWEEP AROUND & CBU. MONITOR WELL. PUMP PILL. SHORT TRIP. OK. DRILL & SURVEY 8-1/2" HOLE F/12495' T/12960'. TIH TO SET CEMENT PLUGS MW: 0.0 VIS: 0 DRILL & SURVEY 8-1/2" HOLE F/12960' T/13087'. BIT. QUIT. POOH T/5850'. MAKE PASS ACROSS SANDS. POOH TO BHA. DOWNLOAD SOURCE & LD CDN, MWD, CDR, LC & STAB.SERVICE WEAR RING & CHANGE OUT BAILS. MU MULE SHOE & TIH TO SET CEMENT PLUGS. WOC MW: 0.0 VIS: 0 TIH T/13080'. CBU. MIX & SPOT CEMENT. BALANCED PLUG F/13080' T/12590'. POOH T/12130'. CIRC OUT CONTAMINATED CEMENT. POOH T/6390'. CBU. MIX & SPOT CEMENT. BALANCED PLUG F/6390' T/5490'. POOH T/5400'. CIRC OUT CONTAMINATED CEMENT. MIX & SPOT CEMENT. BALANCED PLUG F/5450' T/4500' POOH T/4300'. CIRC OUT CONTAMINATED CEMENT. SET STORM PACKER & WR. TEST BOPE. JOHN SPAULDING WITH AOGCC WAIVED WITNESSING TEST. PULL STORM PACKER, INSTALL WR, SERVICE TOP DRIVE, SLIP & CUT DRILL LINE, CIRC & COND MUD WHILE WAITING ON CEMENT. TIH TO SIDETRACK MW: 0.0 VIS: 0 WOC. TIH, TAG CEMENT AT 4410'. JOHN SPAULDING W/AOGCC WAIVED WITNESSING TAGGING OF CEMENT. CBU, MIX AND PUMP CEMENT BALANCED PLUG FROM 4290' TO 3600'. POOH TO CASING SHOE, CBU. POOH, WOC. BHA #3, TIH, WASH DOWN FROM CASING SHOE TO 3628'. TAGGED SOFT CEMENT. WASH CEMENT FROM 3628' TO 3725'. CIRC AND COND MUD. POOH, MU BHA #4. ORIENT AND TEST MWD, TIH TO SIDETRACK. WELL - MPJ-19 OPERATION: RIG - NABORS 22E PAGE: 3 10/28/95 (14) DRILLING 8-1/2" HOLE TD: 5635' ( 0) TIME DRILL & KICK OFF PLUG @ 3795' MW: 0.0 VIS: 0 .... .- .' ' .:.: ' ' '1~;':.. ..., .......; ... ... - ·. ..... ... .... . ..... .,..3 .- .... ', . .'. · .."-.- .,.: . ;.-'.-.-.:..:.-.:.:.-::.:-: ;:.`,`:~;.;.~¢.~;,:..~%;~:~;.~.:.:.?~.:.:~k~;..~`.:"``~:~.~.M.~c:~`¢*~;A~.c86~J`¢~T~%?~*~%.r', f,i'('?.:{;;;C-.?;',';~.¢¢~',]:~.::.;'~,~;.;;;,%:].;,]~¢..~,; .,...~:...~,'",~,L4 ',.~,1 .......... ~' ~ ~'" '"' ~~~'~ ......... ..:.~ ........ :::-::..;--.-:-'~'-..- ..... -..-. ~ ................................................. · ....... ,.....,.. .................... . ........... .... ..... ..,...:..:..........:.._-.,....:.;:,, .... · ' ::. . . - ' ': ' ..-':.' 'i.-.'_-::..::: ';--:-'- '-::~:.-:'.:--'.- .-::'~'::::.k:: '. :.,;. :.'...::'....i ..:.:.:'.::: :..:, .:....:-:,;., .>......:........... ..... . , .... ...... · -' ,,- ':;.--';';..'; ,-.?;-,-;'~';-; ;'-:q-;-;.:-;';:;?h-,-;-:- '>~-:-;';-:~:v~;:.-;-;'%';':'{':':~'.."r':?;<':~¢;*::-'':::''~'-' ' ?:':~. !" ' ~.:'~"!'~'" ¢'?" ;. ' .................. . ' . '. .....:':': ,', . ..-.. - . . .. _ - ......... ' -: --'.--' -..' .'- -'- -'-;.<:-L-:'; ..:.;~;~;~::.~?`.~-;`>.~.;:.~?;``;`~?.``.?.4~.``:~W~`~::`:`?.`~.:=,~`.?~t~.~t~.:.:~.~::.,` !"~" ......... "~' ' ........ :v . . . .... .... ......-.-..- -. . . . ... ' - -- '-, ...... -'- --'-- --% ' ,;-- -- .'-- t' ' ' '- .... ~. ....... ; ..... - ....... .'¥-¥;-:-;'¢;¢.'_':$:'¥;"';'c"': .... ;: ;';;; ;';; :.',;; ;~'~;,;'r..0.~-;~'4, k~,4.,k%4 ..*..:,',.kt4 *; = ~.::: L;',.:.;.;,t-..:'.,-.'.;..5 '..,;,: ,.;; :.'-~:.' '..,''4 ............. ~'".t~"~.~;"~..~¢';':k'.';';',''"- .... - - . --.'.-;.c-c:,?:;..:-~:.-;--:-.:- .... , ....... ,:.::,: ......... ~=,:,~. ..... ; ............ : ..... ~?~t '" ¢....', ~'.*.:.,'.~,:;¢,;;;.14~.~4,'~'.,:f-.~4~-¥,'.4,?: ,, '; ': ::::::::::::::::::::::::::::::::::::::::::::: .......... ~:.~'.,~:;¢.,*,',.'-'~¢-~. :s:.',-,-,,-:.V-.,-,'- :'.-.-~ff; - -....' ......... --...->--~-¢ .............. .-..¢,,.*..-.-~ ;.-'.,-> :----~-- --¢-~-~.--.-,- -.-?.. o ~. '-*-:-- * -_- -?_ ~_-_- :%%: .-: - ,...: -_,_-?-- .-.-:..-,--?.. -.-,-ct'c,'- ~-;,'~--,- '-'~ ~ ': :;¢-.:'c,.'.-?_"::;-;C:'- .'¢?:;C:,;'-%'-.;C;..';':"_ ~- :.'.-'-': t..,--.. .- '. · . - ' .. WELL HEAD LOCATION: LAT(N/-S) 0,00 AZIMUTH FROM ROTARY TABLE TO TARGET TIE IN POINT(TIP) HEASUR~ DEPTH 112o00 TRUE VERT DFJ:I'H 112.00 INCLINATION AZIMUTH 0,00 LATITUDE(W-S) D~PAE~(~-W) DF~'¢£/-W) 0,00 304.8? P~E NO. 2 S!,~£¥ CALCULATIONS ~,~*****tt~ CIRCULAR ARC ItEIHOIIx~,~,;~,~-' ~tBASURED INT~¥AL VERTICAL DEPTH DEPTH fi: ft fi: 205,00 ~,0 ~,~ 1~,0 ~5,~ ~5,~ 100,0 ~4,~ TARGST STATI~ AZI~IJTH LATITUDE S£CTIDN IHCLH, K/-S ft deg. deg. ft 0,00 0,04 0,04 0,00 0,15 0,36 4,60 0,29 0,56 0,44 353.63 0.99 0,69 0,64 26,94 1,87 1,72 0,93 326,77 3,04 DEPARTUR£ DISPLACEIIENT at AZIHLKI14 DLS EJ-W deq./ ft ft tt~ lOOft 0,00 0,00 0,00 0.00 0,02 0,29 4,60 0,39 0.01 0,99 0,35 0.10 0,22 1,88 6,62 0,36. 0,02 3,04 0.47 0,63 605,04 100,0 604,95 705,04 104,0 704,80 805.00 100.0 804,43 055,04 50,0 f)54,11 955,04 100,0 953.04 4,41 2,24 297,19 4,61 9,75 3,97 294,03 6,92 18,01 5,74 291,49 10,16 23,51 7.25 291,25 12.22 37.39 9.49 284.80 16,61 -2,16 5,09 334,93 1,50 -7,06 9,88 314,42 1,74 -14.87 18,01 304,33 1,78 -20,14 23.56 301~24 3,02 -33.9? 37.84 296.04 2,43 1045,04 1055.00 1105.00 1155,00 1205.00 50,0 1002,27 50,0 1051,30 50,0 1100,03 50,0 1148,47 50,0 1196,56 45,60 10,65 284,94 16,86 54,68 12,00 280,47 20,99 64,78 13,60 279,02 22,87 75.90 14.92 278.29 24.73 ~,02 16,87 276,22 26,45 -42,44 46.44 293.95 2.32 -52.02 56.10 291.98 3.22 -63.02 67.04 289.95 3.66 -75.28 79.24 28~.19 2.27 -88,86 92,72 286.57 4.06 1255,00 1305,00 1355,00 1405,00 1455,04 50,0 1244,15 50.0 1291,11 50.0 1337,34 50,0 1302,98 50.0 1428.28 101,34 18,83 274,35 27.85 116,09 21,26 274,32 29,14 132,24 23,54 271,52 30,09 149,25 24,69 271,01 30.54 166,62 25,39 271,01 30,91 -104,12 107.76 284,97 4.08 -121,21 124,67 283.52 4,66 -140,24 143,43 262.11 5,03 -160,66 163.54 280,76 2,34 -181,82 184,43 279,65 1,40 1505,00 1555,00 1605.04 1655.00 1705.00 50,0 1473,37 50,0 1518,07 50,0 1562,30 50,0 1606,05 50,0 1649,29 1~4,73 25,78 270,8~ 31,27 203,53 27,45 273,04 32,05 223,14 28.15 271,19 32,90 243,72 29,81 274,96 34,22 265,19 30.44 272,52 35,85 -203,41 205,60 270,74 0,79 -225.79 228.05 278,08 3.66. -249,09 251,25 277,52 2,22 -273,27 275,40 277,14 4,93 ' -298,30 300,45 276,85 2,75 17b-5.00 1605.00 1855.04 1905.04 1955.04 50,0 1692,16 50,0 1734,50 50,0 1776,39 50,0 1817,73 50,0 1858.59 286.96 31.54 272,71 37,03 309,59 32,72 273.70 38.52 333.07 33.47 274,71 40.52 3b-'7,64 34,98 276,89 43.37 383,14 35,41 277,33 46,94 -324.02 326,13 276,52 2,21 -350,57 352,68 276,27 2.58 -377,80 379,96 276.12 1,66. -405,77 408,06 276,10 3.89 -434,37 436.89 276,17 1,04 2005,00 2055,00 2105,04 2155,00 50,0 1899,18 50,0 1939,18 50,0 1978,51 50,0 2017,26 5O,0 2O55,34 409,17 36,05 278,60 50,99 436,29 37,67 280,58 56,04 464,61 30,61 202,21 62,10 493,85 39.79 283.04 69,04 524,10 41,04 284,82 76,79 -463,28 466,08 276,28 1,96 -492,85 496,02 276,48 4,02 -523.11 526,79 276,77 2,75 -553,95 558.23 277.10 2.56 -585,40 590,42 277,47 3,30 50,0 2092,58 50,0 2128,63 50,0 2164,26 5O,0 2198,81 50,0 2232,43 b'55,69 42,71 287,50 86,09 586,63 44,33 288,30 96,70 622,56 45,44 289,55 108,17 657,53 47,14 290,97 120,69 693,50 48,37 291,63 134,14 -617,43 623,41 277.94 4.95 -650,19 657,34 278,46 3,46 -683,55 692,06 278,9? 2.77 -717,45 727,53 279.5-5 3,97 -751.94 763,81 280.11 2.65 t~J-19 ~ CALCULA?IOb~ ~J~ I~AL V~RTICAL D~TH OEPll-i ft ft ft 2505,00 50.0 2264,80 2555.00 50.0 2296,0B 2605,00 50,0 2326.52 2655,00 50,0 2356.01 2705,00 50.0 ~B4,75 2755,00 2805,00 2905,00 3005,00 3105,00 50,0 2412.60 50.0 2439.59 100.0 2491,48 100,0 2541.48 100.0 2588,84 TAR~lfI 9TATI~ AZIMUTH LATITUDE SECIIOH INCLN, ~-S ft deq d~ ft 7~.78 50,94 294,16 148,97 769.12 51.59 ~4.62 165.08 ~,~ 53,43 ~7,~ 182,~ ~,~ 54,26 ~7,1B 201,14 ~9,~ ~,5~ ~1,1B ~1,~ 930,49 56,73 300.74 242.45 ?72,52 57,94 303,15 264,73 1057,93 59,53 302,22 310,8B 1144,45 60,4B 302,44 357.20 1232,41 62,97 301 ,B7 404.06 D~F'~J~Iq.I~E DISF'LACI~tEHT ~t AZI~TH DLS E/-W deg/ ft ft deq lOOft -787,03 801,00 280.72 6,43 -822,55 838,95 281.35 1,49 -858,16 877.36 282,01 6,03 -894,00 916,34 282,68 1.81 -929,71 955.63 283,38 7.07 -965.32 995,30 284,10 -1001,03 1035.44 284,B1 -1072,97 1117,10 286,16 -1156,15 1200,52 267,31 -1220,71 1285,84 286.31 2,39 4,72 1,78 0.97 2,54 I00,0 2632,36 lOO,O 2674,81 100,0 2719.7B 100.0 2768.13 100.0 2817.71 1322,40 65,45 304,98 453,67 1412,93 64,31 305,54 505,93 1502,24 62,24 305.88 55B,06 1589,72 59,~ 307,46 610,32 1676,49 60,64 306,96 662,83 -1295oB2 1372,94 269,30 -1369,75 1460,20 290,27 -1442,27 1546,47 291,15 -1512,48 1630,97 291,98 -1581,65 1714.92 292,74 3,74 1,25 2,0~ 2,70 0,84 3705,00 3805,00 3905,00 4005,00 4105,00 100,0 28~6,75 100,0 2915,07 1®,0 2961,~ 100,0 3007,0~ 100,0 3050,21 1763,58 60.63 307,16 715,37 1851,10 61,58 305,48 767,23 1939,43 62,57 30~.B2 819,35 2028,61 63,71 305,31 871,86 2118,83 65,~ 3~)4.98 923,80 -1651,1B 1799.49 293,42 -1721,71 1884,92 2?4.02 -1793,05 1971,39 294,56 -1865.17 2056,86 295,05 -1938,94 2147.77 295.48 0,19 1.77 1,54 1,76 1.52 4205,00 4305,00 4405,00 4505.00 4535.00 100,0 30?2,72 100,0 3136.60 100,0 3179,83 100.0 3220,33 30,0 3232,03 2209.35 64,48 304,41 ?75,32 2299.20 63,47 303.95 1025.80 2389,36 65,30 304,44 1076,48 2480.78 66.91 304,15. 1127,99 2500.40 67,18 304,36 1143,54 -2013.36 2237,15 295,85 -2087.70 2326.10 296,17 -2162,28 2415.42- 296,47 -2237,81 2506,02 296,75 -2260,64 2533,41 2?6,53 1,88 1,63 1,11 4565.00 4595,00 4625.00 5655.00 4685.00 30,0 3243,73 30,0 325'5,5O 30.0 3267,22 30,0 3270,85 30,0 3290,48 2536,02 66,91 304.2? 1159.12 2563.62 &A,92 304.52 1174,71 2591.~ 67,08 303,91 1199,24 2618,88 67,28 303,67 1205,62 2646,53 67,10 303,62 1220,94 -?_283,45 2560.60 296,91 -2306,22 2588.17 296.9? -2329,06 2615.57 297,07 -2352,04 2643,03 297,14 -2375,06 2670,51 297,21 0,92 0,71 1.95 1,00 0.62 4715.00 4745,00 4775,00 4805.00 48~.00 30,0 3302,07 30,0 3313,57 30,0 3325,13 30,0 3336,59 30,0 3347,98 2674,19 67,44 303,~6 1236,27 2701,90 67,48 303,94 1251 2729,58 67,21 304,13 1267. lB 2757.30 67,87 304,27 1282,76 2785,05 67,49 304,41 1298,41 -2398,10 2698,01 297,27 -2421,12 2725,54 297,34 -2444,07 2753,03 297,41 -2567.00 2780,57 297,47 -2489,91 2808,12 297,54 1,14 0,07 1,07 2,24 1,34 4865.00 4895.00 4955.00 4965,00 30,0 3359,56 30,0 3371,30 30,0 3383,15 30.0 3395,17 30,0 3407,26 2812,73 67,13 304,50 1314,07 2840,33 66,79 304,27 1329.66 2867,89 66,67 304.36 1345,20 2895,38 ~,07 304,55 1360,76 2922,83 66,43 304,46 1376,31 -2512,73 2835,60 297,61 -2535,52 2863.02 2?7,67 -2558,2B 2890,39 297,74 -2580.94 2917,69 ~7.80 -2603,57 2944,96 297,86 1,23 1,34 0,53 2,07 1,23 PAC£ NO. 4 ..... ~J-19 SUR~ CALOJLATIOblS CIRCULAR ARC MEl140D::~:~* M~ INTEWAL UERTICAL I)~°I'H DEPTH ft fl: fl: 5015.00 30.0 3419.25 5045.00 30.0 3431.33 5075.00 30.0 3443.47 5105,00 30,0 3455,55 5135,00 20,0 2467.59 5165.00 5195.00 5270,58 5365.60 5460.96 30,0 3479.69 20;0 3491.71 75.6 2521,53 95°0 3558,39 95.4 2596,16 TARGET S?ATI~ AZIlqUTH ~Tlll.lI)E SIiCTION I~C~, ~/-S ft deg. deg. it 2950,3*3 66,43 304,37 1391,85 2?77,79 66.0? 304.44 1407,37 2005,22 66,16 204.34 1422.87 2022,66 66,38 304,14 1438,22 2060.16 66,26 ~)4,01 1452,71 3087.60 66.19 303,34 1468.93 3115.08 66.55 303.87 1464.15 3184.52 66,97 204.3? 1523,11 3272,10 67.38 305.94 1573.55 3359.65 65,96 205,46 1624.64 DEP~9~ 1)ISPLAC~ at ft ft -2626,25 2972,28 -2648,91 2999.57 -2671,55 3026,83 -2694,25 3054,14 -2717.01 3081,46 AZIlqUTH deg 297,92 297,98 298,04 298.10 298.15 -2739,85 3108,79 298,20 -2762,74 3136,15 298,24 -2820,23 3205.24 298,37 -2891.82 3292,22 298,55 -2962,93 3379.12 2'78.74 DLS de<)/ lOOft 0.28 1.15 0,38 0,95 0,57 2,06 2.01 0,84 1.56. 1.56 5559,08 .56.54.67 5696.07 5749.77 5845.56 98.1 3637,25 95.6 3679.70 42.2 3698,69 52.9 3721.75 95.8 3761,47 3448,75 64,53 303,75 1675,25 3534,3? 62.75 304.97 1723.58 2572,07 63.75 305,24 1745,25 3619.67 64.56 305,48 1772,80 3706.84 66,44 304.54 1022.80 -2036.26 3467.76 298,89 -3106,97 3553.02 2~.02 -3137,79 2590.49 299,08 -3176,62 2627.82 299.16 -3248.01 3724,54 299,30 2,15 2,19 2.45 1.58 2,15 5939,46 6034,65 6120,43 6223,40 6320.63 93,9 3796,17 95,4 3834.94 95.6 3873.00 92.0 3911.75 97.2 3953,03 375'3.26 67,54 304,71 1871,91 3881.28 67.13 305.0? 1922.26 3968~96 65.94 305,38 1972,86 4053.45 64,79 304.03 2020~97 4141.45 64.97 302,72 2069.40 -3319,13 3810,60 299,42 -3391.32 3898.23 299,55 -34~2,93 3965,48 2~.67 -2532,39 4069,66 299.77 -3605,91 4157.52 299,85 1,16 0.56 1,27 1.81 1.23 6414,61 6509.93 6605.03 6703,06 6796.56 94.0 3992,24 95.3 4030.64 95.1 4068.3~ 90,0 4106,10 95.5 4147.33 4226.82 65.71 303.16 2115.64 4314.00 66,77 302.48 2163.13 4401,23 66.50 302.73 2210.16 4490,76 65.67 302.17 2258,24 4577.73 65.82 201.92 2204.45 -3677.59 4242,81 299.91 -3750,91 432'7.55 2~.97 -3824,45 4417.15 300.02 -3900,07 4506.69 300.07 -3?73.87 4593.71 300.11 1.29 0.37 0.28 6893,27 6989,78 7084.94 7179.06 7275,54 94.7 4185,52 96.5 4224.24 95.2 4263,21 94.1 4302,20 96,5 4342,07 4664,29 66,61 302,21 2350.47 4752,55 66,08 201,20. 23?6,96 4839,23 65.58 ' 301,89 2442.46 4924.77 65,47 301.80 2467.66 5012,51 65,71 202,23 2534,22 -4047.32 4660.33 300.15 -4122.48 4768,69 200.18 -4196,44 4855.48 300,20 -4269,21 4941,11 300.23 -4343,70 5028,92 20Q.26 0,67 1,02 0.77 0.15 0.48 7371.52 7466,64 7560.02 7655,31 7750,64 96,0 4381,30 95,1 4420,05 92.4 4458,10 95,3 4496,96 95,4 4536,65 5100.05 66,04 203.50 2561.76 5186.90 65.89 303,47 2629.69 5272.16 66.02 304.43 2677.31 5259.17 65,86 205,79 2727.25 5445.86 64.94 304.36 2777.18 -4417.28 5116,43 200,30 -4489,73 5203.17 200.~ -4560.47 5288.27 200,42 -4631.64 5375.00 300,49 -4702.59 5461.41 200.56 1,25 0,16 1.31 1.67 7846,46 7941.39 8037.37 8133.60 8228,11 95,8 4577,10 94.9 4616.49 96.0 4655.75 96.2 4694,75 94.5 4732,15 5532.69 65.11 306.10 2827,27 5619,05 65.~6 305,82 2877.?? 5706,61 65,86 206,71 2929,80 5794.53 66.32 306,98 2962,55 5881,27 67,05 206,82 2034,66 -4773.52 5547.97 300.64 -4843,44 5633.98 300,72 -4914,05 5721.16 300,80 -4984,45 ~08.64 300,90 -5053,86 5894.97 300.98 1,65 0,~ 0,85 0,54 0,79 PA~£ NO, ************* ANADRILL ****~***** SUR~ CAI~TIO~S ************* CIRCULAR ARC I~qSk~ I~UIRTICAL ft ft ft 6324,40 96,3 4769,80 8419o02 94,6 4607,18 8514,09 95,1 4045,35 (K-.09,04 55,7 4883,63 6703,35 93,5 4?20,23 TARGET STATIC, A~IMLrtl4 LA~ITUD£ SECTION INCLH. ft ~eq ~eg ft 5969.60 66.92 208.06 3086.54 6056,63 66,54 307.3~ 3141.72 6143.65 66,12 206,20 3193,87 6~31,37 66,75 307.23 3246,34 6317.32 67.15 307.81 3298.74 D~ARllJIU~ DISPLACEM~iT at ft ft -5124,22 5983.03 -5192.98 6069,39 -5262.70 6156,04 -5333,06 6243,41 -5401,30 6328.96 AZIMUTH 301.08 301,17 301.25 301,33 301.41 ~S lOOft 1,20 0,77 1.22 1.16 0.71 8799,63 6894.94 6969,99 90B5.63 9179.90 96.3 4957,82 95,3 4995,44 95.0 5033.46 95.6 5072.42 94.3 5111.40 6405,04 66,89 207,75 3353,04 6493,31 66.62 307,81 3406,69 6580.30 66,21 207,67 3460,01 6667.62 65.75 305,63 3512,16 6753.41 65.29 307,03 3563.00 -TM71,36 6417,06 301,50 -5540.58 6504.12 301.59 -5609,46 6590.73 301.67 -5679,54 6677.76 301.73 -5748,69 6763,31 301.79 0.26 0,29 0,45 2,01 1,40 9276,08 9371,30 9467.33 9563,10 9657,55 96,2 5151,48 55,3 5190,93 95,9 5230,77 95,8 5270,71 94,5 5309,31 6840.82 65.38 303.24 2613,20 6927.56 65,71 303.69 2661.14 7014.78 65.23 202,15 3706.58 7101,73 65.48 202.22 3754,55 7167.68 66,29 303,36 2801.64 -5020.18 6850.58 201.63 -5892,55 6937.30 301.85 -5965.81 7024,56 201.87 -EQ39,48 7111,61 301,87 -6111,94 7197.80 201.8~ 3.58 0,55 1,54 0,27 1,35' 9752.21 9847,12 ~941.74 10035,72 10131.44 94,7 5347,02 94,9 5384,32 94,6 5421.61 94,0 5459,12 95.7 5497.93 7274,70 66,77 304,50 3850.11 7361.96 66,94 305.63 3900,25 7448-.92 66.64 304.I6 3950.02 7535,0B 66.31 203,30 3f~7,88 7622,53 65,85 303.26 4045,89 -6163.98 7284,57 301,91 -6255.40 7371.70 301.94 -6326.72 7458,55 201.98 -6398.37 7544,68 202,00 -6471,52 7632,15 302,01 1,22 1.11 1.44 0.93 0,48 10226.57 10322.&4 1041'6,33 10514,40 10609.26 95,1 5526,81 96,3 5576.16 95,5 5615.21 96.1 5654,47 94.9 5693.48 7709.33 65.91 203,52 4093,67 7797.16 65.65 203.08 4141.92 7&84.27 65,87 303.93 4190.02 7971,94 65.69 303.89 4236.94 6QS8.41 65.55 305,72 4268.29 -6544.01 7718,95 302.03 0.26 -6617.45 7606,80 302,04 0,42 -6690.10 7693.91 202.06 0.81 -6762,87 7981,55 302,08 0.04 -6633.87 8067.91 302,11 1,80 10705.22 108(X).56 10096.31 10991.05 11083.17 96.0 5733,41 55,3 5773.70 95.7 5814.17 94,7 5853,46 92.1 5691.43 8145,64 65.26 306.52 4339.73 8232.03 64,75 305,65 4390.63 8318,79 65.24 206.03 4441.44 8404,98 65.76 206,09 4492,18 048&~5 65.55 306.46 4541.63 -6904,35 8154,95 302,15 -6974.18 8241,17 202.19 -7044,52 6327,76 302,23 -7114.21 8413,78 202,27 -7181,87 0497,50 302,31 0.81 0,99 0.62 0,56 0,44 11175,05 11272.25 I1267,77 11462.60 11557,67 91,9 5929,76 97,2 5971.09 95,5 6013.91 95.0 60'59,96 94,9 6109,06 8572,28 65,15 305,28 4590,76 8660.35 64.53 305.68 4641,63 6745.72 62.19 205,11 4691,28 8828,84 59,84 3(75.26 4729.17 8910,00 57,79 304,75 4785,73 -7249,54 8560,85 302,34 -7321,19 8668,70 302,30 -7390,77 6753,95 302,41 -7458.71 &836,98 302,43 -7525,18 6918,05 202,45 1.25 0.74 2,50 2,49 2,21 11651,42 11744.69 11040.12 11935,59 12020.46 93+7 6160.31 93.3 6213.63 95,4 6270.73 95,5 6330.35 94.9 6391.68 8986.50 55,97 303.72 4829,91 9065.02 54.20 304,78 4672.97 9141.46 52.18 203,40 4915,83 9216,01 50,52 204,19 4957.30 9286,39 48.94 305.22 499~.51 -7590o08 8~6,52 202,47 2,15 -7653,35 ~73,01 202,49 2,01 -7716,65 9149,43 302,50 2,50 -7778,61 9223,97 302,51 1.66 -7638,12 9296,30 302,53 1.86 PAGE NO, 6 ....... ~J-19 ****~**** ANAl)RILL ************** SUR~q~ CALCULATIONS ~~**** CIRCLF~ ARC ~EASUt~ I~-th~ U~TICAL I)]~'TH I)EPll4 ft f~ ft 12124,~ ~,8 ~54,34 1~18,~ 94,2 6519.57 1~13,~ 94.7 6~7,~ 12~,54 ~,5 1~3,97 97,4 6727,24 TARG~ STATI~ AZI~EKIH LATIlt)I)E $~'~ION I~I~. ft deg deg it 9358,12 47.17 304.71 5038,48 9426.03 45,14 304,92 5077.25 9492,15 43.51 307,11 5116.12 9556.01 42,73 306.84 5154,56 9621.93 42.50 307.18 5194,27 DE~AR~£ ~ISPLAC~ at ~-W ft it -7895.26 ~5.97 -7~1,01 9433.02 -1~:)04.51 9499.04 -OOb~,~7 956;3,56 -8108,24 9629,33 AZI~LITH 302,54 302.56 302,5~ 302,61 302,64 DLS lOOft 1,93 2.16 2.35 0,86 0,33 12597,35 93,4 6795,91 12692.86 95.5 6865,87 12784,50 91,6 6932,85 12679.14 94,6 7001,95 12973,65 94,5 7071,35 9685,13 42,83 300,60 5233.13 9749.96 42.97 309,77 5274.21 9812.33 43,11 300,77 5313,00 9876,88 43.09 307.71 5353.82 9940.90 42,41 309,18 5393.70 -815~, 1B 9692,35 302.68 -8208.58 9~6,95 302,72 -8257,00 9819.09 302,76 -8307,79 9863,46 302.80 -8358,02 9947,29 302.84 1,10 0,64 0.76 0,76 1,28 12999.99 26.3 7090,84 13087.00 87.0 7155,32 9958,58 42.18 307,99 5404.76 10016.93 42,18 306,00 5440.73 -0371,~ 9964,93 302,85 -6417,92 10023,12 302.8~ 3.16 0,02 gyro/data B.P. EXPLORATION J-PAD, MPJ-19 MILNE POINT, ALASKA Gyro Multishot Survey in 5" Drillpipe Survey date: 20 October, 1995 Job number: AK1095G301. SR301.DOC Gyrodata Incorporated P.O. Box 79389 Houston, Texas 77279 713/461-3146 Fax: 713/461-0920 October26, 1995 B.P. Exploraton (Alaska) Inc. Petrotechnical Data Center, MB 3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 J-Pad, MPJ-19, Milne Point, Alaska Enclosed please find one (1) original and six copies (6) of the completed survey of Well #MPJ-19 We would like to take this opportunity to thank you for using Gyrodaata and we look forward to serving you in the future. Sincerely Operations Manager RS/fec Serving the Worldwide Energy Industry with Precision Survey Instrumentation _gyro/data CONTENTS JOB NUMBER :AK1095G301 1. DISCUSSION , SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR301 .DOC gyro/data 1. DISCUSSION , SURVEY CERTIFICATION SHEET SR301 .DOC gyro/data DISCUSSION JOB NUMBER · AK1095G301 Tool 080 was run in J-pad well number MPJ-19 inside of 5" drillpipe on Atlas 15/32 wireline. The survey was run without problems. SR301 .DOC gyro/data SURVEY CERTIFICATION SHEET JOB NUMBER: AK1095G301 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOIVi STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the wellsite. ~- Checked by :- ROB SHOUP OPERATIONS MANAGER SR301 .DOC gyro/data 2. SURVEY DETAILS SR301.DOC gyro/data SURVEY DETAILS JOB NUMBER: AK1095G301 CLIENT: B.P. EXPLORATION RIG: NABORS RIG 22E LOCATION: Milne Point WELL: MPJ-19 LATITUDE: 70.450 LONGITUDE: W S U RVEY DATE: 20-Oct.,1995 SURVEY TYPE : DEPTH REFERENCE: MAX. SURVEY DEPTH: MULTISHOT IN 5" drillpipe ROTARY TABLE ELEVATION 64.5 asl 5195.0 SURVEY TIED ONTO: N/A SURVEY INTERVAL: 100'and 30' UTM CO-ORDINATES: TARGET DIRECTION: 303.53 GRID CORRECTION: CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: STODDARD SR301.DOC 'gyro/data 3. OUTRUN SURVEY LISTING SR301.DOC A Gyro da t a D i r e c t i o na i Survey for B.P. EXPLORATION WELL: J-PAD, MPJ-19 Location: NABORS 22E, MILNE POINT, ALASKA Job Number: AK1095G301 Run Date: 20-0ct-95 06:45:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.450000 deg. N Sub-sea Correction from Vertical Reference: 64.5 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 303.530 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyro d a t a D i r e c t i o na i Survey B.P. EXPLORATION WELL: J-PAD, MPJ-19 Location: NABORS 22E, Job Number: AK1095G301 MILNE POINT, ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SUBSEA SECTION DEPTH feet feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 0.0 0.00 0.00 0.0 0.0 -64.5 0.00 0.0 0.0 0 - 5195 FT. GYRO SURVEY RUN IN 5" DRILLPIPE. MEASURED DEPTHS ARE REFERENCED TO THE NABORS RIG 22E R.K.B. A DEPTH CORRECTION OF 5 FT. WAS MADE TO THE FINAL SURVEY. AT 64.5 FT. ABOVE S O.O0'N 0.00 E 105.0 .16 348.26 105.0 .1 40.5 .16 205.0 .36 4.60 205.0 .4 140.5 .21 305.0 .44 353.63 305.0 .8 240.5 .11 405.0 .64 26.94 405.0 1.1 340.5 .37 505.0 .93 326.77 505.0 1.9 440.5 .83 · 2 348.3 · 6 356.8 1.3 357.7 2.2 4.2 3.4 359.5 .15 N .03 W .60 N .03 W 1.30 N .05 W 2.19 N .16 E 3.37 N .03 W 605.0 2.24 297.19 604.9 4.6 540.4 1.51 705.0 3.97 294.03 704.8 9.9 640.3 1.74 805.0 5.74 291.49 804.4 18.2 739.9 1.78 855.0 7.25 291.25 854.1 23.8 789.6 3.01 905.0 8.33 289.34 903.6 30.4 839.1 2.22 5.4 335.8 10.2 315.5 18.3 305.1 23.8 301.8 30.5 299.3 4.94 N 2.22 W 7.25 N 7.12 W 10.49 N 14.94 W 12.55 N 20.21 W 14.89 N 26.57 W 955.0 9.49 284.80 953.0 37.8 888.5 2.71 1005.0 10.65 284.94 1002.3 46.1 937.8 2.33 1055.0 12.00 280.47 1051.3 55.2 986.8 3.22 1105.0 13.80 279.02 1100.0 65.4 1035.5 3.66 1155.0 14.92 278.29 1148.5 76.7 1084.0 2.26 38.1 296.8 46.6 294.6 56.3 292.5 67.2 290.4 79.4 288.6 17.14 N 33.91 ? 19.39 N 42.42 W 21.53 N 52.00 W 23.41 N 63.00 W 25.27 N 75.27 W 1205.0 16.87 276.22 1196.6 89.0 1132.1 4.06 1255.0 18.83 274.35 1244.1 102.5 1179.6 4.09 1305.0 21.26 274.32 1291.1 117.4 1226.6 4.86 1355.0 23.54 271.52 1337.3 133.8 1272.8 5.04 1405.0 24.69 271.01 1383.0 151.1 1318.5 2.33 92.9 286.9 107.9 285.3 124.8 283.8 143.5 282.3 163.6 280.9 26.99 N 88.85 W 28.38 N 104.11 W 29.68 N 121.20 W 30.63 N 140.23 W 31.08 N 160.65 W A Gyr oda t a D i r e c t i o na i Survey B.P. EXPLOP~ATION WELL: J-PAD, MPJ-19 Location: NABORS 22E, Job Number: AK1095G301 MILNE POINT, ALASKA MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet 1455.0 25.39 271.01 1428.3 1505.0 25.78 270.88 1473.4 1555.0 27.45 273.04 1518.1 1605.0 28.15 271.19 1562.3 1655.0 29.81 274.96 1606.0 1705.0 30.44 272.52 1649.3 1755.0 31.54 272.71 1692.2 1805.0 32.72 273.70 1734.5 1855.0 33.47 274.71 1776.4 1905.0 34.98 276.89 1817.7 1955.0 35.41 277.33 1858.6 2005.0 36.05 278.60 1899.2 2055.0 37.67 280.58 1939.2 2105.0 38.61 282.21 1978.5 2155.0 39.79 283.00 2017.3 2205.0 41.00 284.82 2055.3 2255.0 42.71 287.50 2092.6 2305.0 44.33 288.38 2128.8 2355.0 45.44 289.55 2164.3 2405.0 47.14 290.97 2198.8 2455.0 48.37 291.63 2232.4 2505.0 50.94 294.16 2264.8 2555.0 51.59 294.62 2296.1 2605.0 53.43 297.63 2326.5 2655.0 54.26 297.18 2356.0 168.9 187.1 206.2 226.1 247.0 268.8 290.8 313.8 337.6 362.5 388.3 414.6 442.1 470.7 500.2 530.7 562.5 595.7 629.8 665.0 701.2 738.6 777.2 816.5 856.6 SUBSEA DOGLEG CLOSURE DEPTH SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. 1363.8' 1408.9 1453.6 1497.8 1541.5 1584.8 1627.7 1670.0 1711.9 1753.2 1794.1 1834.7 1874.7 1914.0 1952.8 1990.8 2028.1 2064.3 2099.8 2134.3 2167.9 2200.3 2231.6 2262.0 2291.5 1.39 184.5 279.8 .81 205.9 278.9 3.85 228.1 278.2 2.22 251.3 277.6 4.94 275.5 277.2 2.76 300.5 277.0 2.20 326.2 276.6 2.60 352.7 276.4 1.86 380.0 276.2 3.89 408.1 276.2 .99 436.9 276.2 1.97 466.1 276.3 4.02 496.1 276.5 2.75 526.8 276.8 2.57 558.3 277.2 3.38 590.5 277.5 4.95 623.5 278.0 3.46 657.4 278.5 2.77 692.1 279.0 3.98 727.6 279.6 2.64 763.9 280.2 6.43 801.1 280.8 1.49 839.0 281.4 6.02 877.5 282.0 1.82 916.5 282.7 Page 2 HORIZONTAL COORDINATES feet 31.45 N 181.81 W 31.80 N 203.40 32.58 N 225.79 ~ 33.44 N 249.09 W 34.76 N 273.26 W 36.39 N 298.30 W 37.56 N 324.01 W 39.05 N 350.56 W 41.06 N 377.79 W 43.91 N 405.76 W 47.48 N 434.35 W 51.52 N 463.27 W 56.53 N 492.84 W 62.64 N 523.11 W 69.54 N 553.94 W 77.33 N 585.39 86.63 N 617.43 W 97.24 N 650.18 W 108.71 N 683.55 W 121.23 N 717.45 W 134.68 N 751.93 W 149.52 N 787.02 W 165.62 N 822.54 W 183.10 N 858.15 W 201.68 N 893.99 W A Gyro da t a D i r e c t i o na i Survey B.P. EXPLORATION WELL: J-PAD, MPJ-19 Location: NABORS 22E, Job Number: AK1095G301 MILNE POINT, ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SUBSEA DOGLEG CLOSURE SECTION DEPTH SEVERITY DIST. AZIMUTH feet feet deg./ feet deg. 100 ft. HORIZONTAL C 0 0 R D I N A T E S feet 2705.0 55.59 301.18 2384.8 2755.0 56.73 300.74 2412.6 2805.0 57.94 303.15 2439.6 2905.0 59.53 302.22 2491.5 3005.0 60.48 302.44 2541.5 897.4 2320.3 '7.07 955.7 283.4 938.9 2348.1 2.40 995.4 284.1 981 . 0 2375 . 1 4 . 72 1035 . 6 284 . 8 1066 . 4 2427 . 0 1 . 78 1117 . 2 286 . 2 1153 . 0 2477 . 0 . 97 1200 . 7 287 . 3 221.63 N 929.69 w 243.00 N 965.31 265.27 N 1001.02 W 311.42 N 1072.96 W 357.74 N 1146.13 W 3105.0 62.97 301.87 2588.8 3205.0 65.45 304.98 2632.4 3305.0 64.31 305.54 2674.8 3405.0 62.24 305.88 2719.8 3505.0 59.92 307.46 2768.1 1241.1 2524.3 2.55 1286.0 288.3 1331.1 2567.9 3.74 1373.1 289.3 1421.6 2610.3 1.25 1460.4 290.3 1510.8 2655.3 2.10 . 1546.7 291.2 1598.2 2703.6 2.70 1631.2 292.0 404.60 N 454.20 N 506.47 N 558.60 N 610.85 N 1220.69 W 1295.81 W 1369.74 W 1442.26 W 1512.46 W 3605.0 60.64 306.96 2817.7 3705.0 60.63 307.18 2866.8 3805.0 61.58 305.48 2915.1 3905.0 62.57 306.82 2961.9 4005.0 63.71 305.31 3007.1 1684.9 2753.2 .85 1715.1 292.8 1771.9 2802.3 .19 1799.7 293.4 1859.3 2850.6 1.77 1885.1 294.0 1947.6 2897.4 1.54 1971.6 294.6 2036.7 2942.6 1.77 2059.1 295.1 663.37 N 715.90 N 767.76 N 819.89 N 872.40 N 1581.63 W 1651.17 W 1721.70 W 1793.04 W 1865.15 W 4105.0 65.20 304.98 3050.2 4205.0 64.48 304.41 3092.7 4305.0 63.47 303.95 3136.6 4405.0 65.30 304.44 3179.8 4505.0 66.91 304.15 3220.3 2126.9 2985.7 1.52 2148.0 295.5 2217.3 3028.2 .88 2237.4 295.9 2307.2 3072.1 1.08 2326.3 296.2 2397.4 3115.3 1.88 2415.6 296.5 2488.8 3155.8 1.63 2506.3 296.8 924.33 N 975.85 N 1026.33 N 1077.01 N 1128.52 N 1938.93 2013.34 W 2087.68 W 2162.26 W 2237.80 W 4535.0 67.18 304.36 3232.0 4565.0 66.91 304.29 3243.7 4595.0 66.92 304.52 3255.5 4625.0 67.08 303.91 3267.2 4655.0 67.28 303.67 3278.9 2516.4 3167.5 1.12 2533.6 296.8 2544.0 3179.2 .93 2561.0 296.9 2571.6 3191.0 .71 2588.4 297.0 2599.2 3202.7 1.95 2615.8 297.1 2626.9 3214.4 1.00 2643.3 297.1 1144.07 N 1159.65 N 1175.25 N 1190.77 N 1206.15 N 2260.63 W 2283.44 W 2306.21 W 2329.05 W 2352.03 W A Gyro da t a D i r e c t i on a i Survey B.P. EXPLORATION WELL: J-PAD, MPJ-19 Location: NABORS 22E, Job Number: AK1095G301 MILNE POINT, ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SUBSEA DOGLEG CLOSURE SECTION DEPTH SEVERITY DIST. AZIMUTH feet feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 4685.0 67.10 303.62 3290.5 4715.0 67.44 303.66 3302.1 4745.0 67.48 303.94 3313.6 4775.0 67.21 304.13 3325.1 4805.0 67.87 304.27 3336.6 2654.5 3226.0 .64 2670.7 297.2 2682.2 3237.6 1.15 2698.2 297.3 2709.9 3249.1 .86 2725.8 297.3 2737.6 3260.6 1.07 2753.3 297.4 2765.3 3272.1 2.24 2780.8 297.5 1221.48 N 2375.05 1236.80 N 2398.09 1252.22 N 2421.11 1267.71 N 2444.05 1283.30 N 2466.99 4835.0 67.49 304.41 3348.0 4865.0 67.13 304.50 3359.6 4895.0 66.79 304.27 3371.3 4925.0 66.67 304.38 3383.2 4955.0 66.07 304.55 3395.2 2793.1 3283.5 1.36 2808.4 297.6 2820.8 3295.1 1.23 2835.8 297.6 2848.4 3306.8 1.32 2863.3 297.7 2875.9 3318.7 .52 2890.6 297.7 2903.4 3330.7 2.05 2917.9 297.8 1298.95 N 1314.61 N 1330.20 N 1345.74 N 1361.29 N 2489.90 W 2512.72 W 2535.51 W 2558.27 W 2580.93 W 4985~0 66.43 304.46 3407.3 5015.0 66.43 304.37 3419.3 5045.0 66.09 304.44 3431.3 5075.0 66.16 304.34 3443.5 5105.0 66.38 304.14 3455.5 2930.9 3342.8 1.22 2945.2 297.9 2958.3 3354.8 .29 2972.5 297.9 2985.8 3366.8 1.15 2999.8 298.0 3013.2 3379.0 .40 3027.1 298.0 3040.7 3391.0 .94 3054.4 298.1 1376.85 N 1392.39 N 1407.91 N 1423.41 N 1438.86 N 2603.56 W 2626.24 W 2648.90 W 2671.53 W 2694.24 W 5135.0 66.26 304.01 3467.6 5165.0 66.19 303.34 3479.7 5195.0 66.55 303.87 3491.7 3068.2 3403.1 .58 3081.7 298.2 3095.6 3415.2 2.04 3109.0 298.2 3123.1 3427.2 2.01 3136.4 298.3 1454.25 N 1469.47 N 1484.69 N 2716.99 2739.84 W 2762.73 W Final Station Closure: Distance: 3136.40 ft Az: 298.25 deg. A Gyroda t a D i r e c t i o n a i Survey for ., B.P. EXPLORATION WELL: J-PAD, MPJ-19 Location: NABORS 22E, MILNE POINT, ALASKA Job Number: AK1095G301SS Run Date: 20-Oct-95 06:45:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.450000 deg. N Sub-sea Correction from Vertical Reference: 64.5 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 303.530 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyro da t a D i r e c t i o na i Survey B.P. EXPLORATION WELL: J-PAD, MPJ-19 Location: NABORS 22E, MILNE POINT, Job Number: AK1095G301SS ALASKA Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG DEPTH DEPTH SECTION SEVERITY feet deg. deg. feet feet deg./ 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet '-64.5 0.00 0.00 0.0 0.0 0.00 0.0 0.0 0.00 N 0.00 E ' 0 - 5195 FT. GYRO SURVEY RUN IN 5" DRILLPIPE. MEASURED DEPTHS ARE REFERENCED TO THE NABORS RIG 22E R.K.B. A DEPTH CORRECTION OF 5 FT. WAS MADE TO THE FINAL SURVEY. AT 64.5 FT. ABOVE S 100.0 .28 357.98 164.5 .3 .19 200.0 .41 358.07 264.5 .6 .15 300.0 .56 13.45 364.5 .9 .26 400.0 .81 205.38 464.5 1.6 .64 500.0 1.71 309.16 564.5 3.5 1.23 · 6 353.3 1.3 357.3 2.2 1.6 3.4 1.4 5.4 345.4 · 42 N .03 W 1.02 N .04 W 1.83 N .12 E 2.89 N .08 W 4.31 N 1.33 W 600.0 3.27 295.30 664.5 7.8 1.64 700.0 5.03 292.51 764.5 14.9 1.76 800.0 7.48 290.84 864.5 25.2 2.85 900.0 9.76 284.83 964.5 39.7 2.62 1000.0 12.49 280.08 1064.5 58.0 3.34 10.2 323.7 18.3 309.3 30.5 301.3 46.6 296.3 67.2 291.9 6.32 N 5.14 W 9.19 N 11.81 W 13.04 N 21.54 W 17.67 N 35.94 W 22.04 N 54.98 W 1100.0 15.57 277.60 1164.5 80.8 2.86 1200.0 19.89 274.34 1264.5 109.0 4.42 1300.0 24.23 271.22 1364.5 144.1 3.43 1400.0 25.71 270.90 1464.5 183.5 .92 1500.0 28.23 271.38 1564.5 227.2 2.36 92.9 288.0 124.8 284.6 163.6 281.5 205.9 279.1 275.5 277.6 25.84 N 79.79 W 28.95 N 111.52 W 30.90 N 152.39 W 31.73 N 199.16 W 33.50 N 250.30 W 1600.0 30.83 272.59 1664.5 276.6 2.56 1700.0 33.26 274.42 1764.5 330.8 2.07 1800.0 35.50 277.51 1864.5 392.1 1.13 1900.0 38.28 281.63 1964.5 460.5 3.20 2000.0 41.42 285.48 2064.5 538.5 3.76 326.2 276.8 380.0 276.2 466.1 276.3 526.8 276.7 623.5 277.6 36.80 N 307.42 W 40.49 N 370.06 W 48.07 N 438.56 W 60.46 N 512.32 W 79.62 N 593.28 W A Gyro da t a D i r e c t i on a i Survey B.P. EXPLORATION WELL: J-PAD, MPJ-19 Location: NABORS 22E, MILNE POINT, ALASKA Job Number: AK1095G301SS SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DEPTH DEPTH SECTION feet deg. deg. feet feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. Page HORIZONTAL COORDINATES feet 2100.0 45.45 289.56 2164.5 630.1 2200.0 50.92 294.14 2264.5 738.3 2300.0 54.65 298.36 2364.5 868.7 2400.0 58.70 302.70 2464.5 1022.0 2500.0 61.69 302.16 2564.5 1195.8 2.78 727.6 279.0 6.39 801.1 280.8 3.37 955.7 282.9 3.31 1117.2 285.5 1.74 1286.0 287.8 108.79 N 683.78 W 149.38 N 786.70 W 207.57 N 904.53 W 287.43 N 1035.55 W 380.51 N 1182.36 W 2600.0 64.59 305.41 2664.5 1399.6 2700.0 60.09 307.34 2764.5 1591.6 2800.0 60.63 307.17 2864.5 1767.9 2900.0 62.63 306.74 2964.5 1952.7 3000.0 64.96 304.78 3064.5 2157.3 1.85 1460.4 290.1 2.65 1631.2 291.9 .22 1799.7 293.4 1.56 2059.1 294.6 1.30 2237.4 295.6 493.77 N 606.92 N 713.49 N 822.90 N 941.64 N 1351.78 W 1507.17 W 1647.97 W 1797.18 W 1963.92 W 3100.0 64.65 304.27 3164.5 2365.4 3200.0 67.04 304.05 3264.5 2592.8 3300.0 66.99 304.40 3364.5 2832.4 3400.0 66.29 304.04 3464.5 3061.1 3427.2 66.55 303.87 3491.7 3123.1 1.60 2415.6 296.4 1.66 2615.8 297.1 1.27 2863.3 297.6 .67 3081.7 298.1 2.01 3136.4 298.3 1059.03 N 1187.17 N 1321.17 N 1450.30 N 1484.69 N 2135.80 W 2323.75 W 2522.31 W 2711.15 W 2762.73 W Final Station Closure: Distance: 3136.40 ft Az: 298.25 deg. gyro/data 4. QUALITY CONTROL SR301.DOC Quality Control Comparisons B.P. EXPLORATION WELL: J-PAD, MPJ-19 Location: NABORS 22E, MILNE POINT, ALASKA Job Number : AK1095G301 / AK1095G301 INRUN/OUTRUN Comparison INRUN OUTRUN INRUN Depth Inc Inc Delta Az 505.0 .87 .93 -.057 329.18 1005.0 9.99 10.65 -.667 286.26 1505.0 25.93 25.78 .146 271.51 2205.0 40.75 41.00 -.247 283.86 For Inclinations Greater than 10 degrees: Average Inclination Difference = -.2559 deg. Average Azimuth Difference = .33417 deg. OUTRUN Az 326.77 284.94 270.88 284.82 Delta 2.408 1.321 .634 -.953 gyro/data QUALITY CONTROL REPORT JOB NUMBER: AK1095G301 TOOL NUMBER: O80 MAXIMUM GYRO TEMPERATURE: 74.4c MAXIMUM AMBIENT TEMPERATURE: 22.6 c MAXIMUM INCLINATION: 67.87 AVERAGE AZIMUTH: 298.25 WIRELINE REZERO VALUE: 5 feet REZERO ERROR / K: n/a CALIBRATION USED FOR FIELD SURVEY: 8/21/95 CALIBRATION USED FOR FINAL SURVEY: 8/21/95 PRE JOB MASS BALANCE OFFSET CHECK: .19 POST JOB MASS BALANCE OFFSET CHECK]: CONDITION OF SHOCK WATCHES -.04 USED .00 UPON ARRIVAL AT RIG: OK UPON COMPLETION OF SURVEY: OK UPON RETURN TO ATLAS OK BOTTOM LINE COMPARISONS: M.D. INC AZIMUTH TVD NORTHING EASTING FIELD SURVEY 5195 66.55 303.87 3491.7 1484.69N 2762.73W FINAL SURVEY 5195 66.55 303.87 3491.7 1484.69N 2762.73W SR301 .DOC gyro/data FUNCTION TEST JOB NUMBER: AK1995G301 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft 1 2 3 4 5 2205 40.45 40.45 40.45 40.45 40.45 AZIMUTH M.D. ff 1 2 3 4 5 2205 284.2 284.2 284.1 283.99 283.86 SR301.DOC gyro/data 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR301.DOC gyro/data EQUIPMENT REPORT JOB NUMBER: AK1095G301 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 080 GYRO SECTION A0098 DATA S ECTI ON A0032 POWER SECTION A0027 BACKUP TOOL No. 731 GYRO SECTION A0054 DATA SECTION A0025 POWER SECTION A0052 COMPUTER POWER SUPPLY PRINTER INTERFACE COMPUTER POWER SUPPLY PRINTER INTERFACE A0153 A0074 A0079 A0071 A0122 A0074 A0082 A0035 WIRELINE COMPANY: CABLE SIZE: ATLAS WIRELINE 15/32 RUNNING GEAR 2 1/4" System TOTAL LENGTH OF TOOL MAXIMUM O.D.: 17.5 feet 2.25 INCHES TOTAL WEIGHT OF TOOL: 190 Lbs SR301 .DOC PERMIT DATA 95-159 CDN-MD 95-159 CDN-TVD 95-159 CDR-TVD 95-159 CDR-MD AOGCC Individual Well Geological Materials inventory T DATA_PLUS o ~..A~3350-12970 ~-A~700-7110 ~L~700-7110 ~/3400-13300 Page: 1 Date: 07/28/97 RUN DATE_RECVD FINAL 12/29/95 FINAL 12/29/95 FINAL 12/29/95 FINAL 12/29/95 10-407 COMPLETION DATE DAILY WELL OPS --R /..~;/tj"'/$';-"/ TO lO/,~/~//"/ Are dry ditch samples required? yes ~__And received? Was the well cored? yes ~Analysis & description received? _ yes no. Are well tests required?~es ~_~Received? Well is in compliance Initial COMMENTS PLUGGING & LOCATION CLEARANCE REPORT State of Alaska A/~ASKA OiL & GAS CONSERVATION COMMISSION 157 );emcrand"_?. To File: Note casing size, wt, Liner: ._-._or 370. Well Name Ouerator Location depth, cmt vol, , Completed perf intez-zals - tops: Review the well file, and-comment on plugging, well head st. atus, and location clearance - provide loc. clear, code. Well head cut off: Marker post or plate: Location Clearance: ~o Conclusions: · Code Signed Date Schlumberger - GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage, Alaska 99518-1199 (907) 562-7669 (Bus.) (907) 563-3309 (Fax) December 27, 1995 TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3~3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the .CDR/CDN,CDRICDN TVD',S for well IvIPJ-19 Job # 95363 was sent to: 1 OH LIS Tape 3 Bluelines each I Film each BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 State__e_ f-A!¢s~a' .~/ATa~ka Oil & Gas Conservation Comm. /' Attn: Larry Grant Q,3001 Porcupine Drive Anchorage, Alaska 99501 1 OH LIS'T. gpe 1 Blueline e~ch 1 RF Sepia each OXY USA, Inc Attn' Darlene Fairly P.O. Box 50250 Midland, Texas 79710 1 OH LIS Tape 1 Blueline each 1 RF Sepia each Sent Certified Mail Z 777 937 365 NOTE: NO DEPTH SHIFTING PERFORMED PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO' BP EXPLORATION (ALASKA) INC. PETRO1ECHNICAL DATA CENTER, MB3-3 900 EAST BENSON BLVD. ANCHORAGE, ALASKA 99519-6612 Schlumberger Cotmer: te Delivered: SCHLUMBERGER GEOQUEST 500 WEST INTERNATIONAL AIRPORT ROAD ANCHORAGE, AL~ _...~¢,~. ~ij~l~- -~11//~E9 a Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED E~ SERVICE [] 2. Name of Operator 7. Permit Number .BP Exploration (Alaska) Inc. _,,.~ 95-159 3. Address(.~ ~ APl Number · ~/5~,- 029-22607 P. O. Box 196612, Anchorage, Alaska 99519-6612 ~,. Location of well at surface¢,~_~.._._~. .........: l~..~tlo} Lease Name 2234' NSL, 2201' WEL, SEC 28, T12N, RIOE '~~" ~ I~iCf'~i~t Unit At Top Producing Interval N/A ~ ~"'~'- ~ MPJ' I'9C&// ?~- ,~~...! 11. Field and I~,,ol At Total Depth .................... - Milne Point/Kuparuk River Sands 2391' NSL, 1146' WEL, SEC 19, T13N, RIOE 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 64.5' ADL 025515 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 10/16/95 10/24/95 10/25/95I N/A feet MSLI Zero 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+I-VD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 13087' MD / 7120' 7-VD 13087' MD / 7120' TVD YES [] r~O []I None feet MD 1800' (Approx.) 22. Type Electric or Other Logs Run Gyro, MWD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 Surface 112' 24" 250 Arctic Set I (Approx.) 9-5/8" 40# L-80 31' 3391' 12-1/4" 674 sx PF 'E', 250 sx 'G', 150 sx PF 'E' 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET IMD) PACKER SET(MD) N/A None 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12590' - 13080' 250 SX °G' Balanced Plug 5490' - 6390' 400 sx 'G' Balanced Plug 4500' - 5450' 400 sx 'G' Balanced Plug 3600' - 4290' 275 sx 'G' Balanced Plug 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) Not on Production I N/A Date of Test Hours Tested PRODUCTION FOR 31L-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED..~ DIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. 05 1995 Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. (Subsea) Top Kuparuk 'B' 12789' 6871' Top Kuparuk 'A' 12953' 6991' Top Kuparuk 'A3' 12968' 7002' Top Kuparuk 'A2' 13008' 7032' " NOV 05 1995 ~....i~k~ U~t & Gas Cons. C0r~;::'.:~,~ Anchorage 31. LIST OF A-I-FACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge · Signed ' Title SeniorDrillina Engineer Date // ~ - -! f INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: October 25, 1995 To: From' Subject: Blair Wonzell, Senior Petroleum Engineer, AOGCC Randy Thomas, Drilling Superintendent, SSD MPJ-19A Permit for Sidetrack The attached Permit Package is being submitted due to the unforseen results of the original MPJ-19 well, i.e the Kuparuk Sands were wet. As is the case with most wells in the MPJ area the considered viable alternative in this case is to salvage at least the Schrader Bluff Sand package. The sidetrack is necessary because in the original well (J-19) the Schrader Bluff package was penetrated at an angle of approximately 67° which makes completion with ESP equipment not practicable. A lower angle (40° - 45°) through the section is required. . To this end the attached Package is being submitted for your approval at your earlieSt d0nvenience. Further, a summary of operations, or planned operations, to the point of actually sidetracking out of the existing MPJ-19 welibore follows. (Verbal approval from Jack Harts and yourself for the following procedure) 1) Drilled 8.5" hole to 13087' md. LWD showed the target Kuparuk sands to be wet. 2) Decision made to sidetrack and make the well a Schrader Bluff producer. 3) Plan submitted to AOGCC for P&A of existing J-19 wellbore as follows: Set P&A Plug #1 from TD (13087') to 200' above the Kuparuk B sand or 12590' to solate the Kuparuk Sands. This plug would not be tagged; Set P&A Plug #2 in two stages from 50' below the CC Sands to 200' above the MA sands to isolate the Schrader Bluff Package in the original wellbore. This plug will be tagged and the AOGCO Representative notified to witness the tag, if applicable; Set P&A/Sidetrack Plug #3 in one stage from 4290' to 3790' - the planned KOP for MPJ19A. 4) Once P&A plugs are inplace the top cement plug will be dressed off to 3790' and'-the well kicked-off to the new Schrader Bluff target as noted in the APD. NOV 05 1995 Gas Cens. I;0m~:-~i:'.~.a.'.~:.k_a, .(Ji! .& G~s Cons. N~chorage 'J'-: Anchorage BP/ALI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: MPJ-19 BOROUGH: NORTH SLOPE UNIT: UNKNOWN FIELD: UNKNOWN LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 10/15/95 06:00 SPUD: RELEASE: 10/30/95 12:00 OPERATION: DRLG RIG: NABORS 22E WO/C RIG: 10/15/95 (1) TD: 112' ( 112) 10/16/95 (2) TD: 112'( 0) 10/17/95 (3) TD: 2297' (2185) 10/18/95 ( 4) TD: 3421' (1124) 10/19/95 (5) TD: 3421' ( 0) 10/20/95 (6) TD: 5548' (2127) MOVING SUB MW: 0.0 VIS: 0 INSTALL NEW FLUID END ON MUD PUMP. BLOW DOWN & MOVE SUB F/I-PAD T/J-PAD. PU BHA MW: 0.0 VIS: 0 MIRU. RIG ACCEPTED @ 1800 HRS., 10/15/95 MPJ-19. NU DIVERTER SYSTEM, CHANGING OUT FLUID END & DISCHARGE MANIFOLD ON PUMP, MODIFY PITCHER NIPPLE & NU FLOWLINE. MIX MUD. PU TOOLS & CLEAN RIG. PU HWDP & DP. ,- DRILLING MW: 0.0 VIS: 0 FUNCTION TEST DIVERTER. MU BIT, CHANGE MOTOR. PU BHA, SURFACE CHECK MUD SYSTEM. ATTEMPT TO SPUD, FLOWLINE PLUGGED WITH SACKS FROM CONDUCTOR. DRILL F/l12' T/1154'. SHORT TRIP. OK. DRILL F/1154' T. 2201'. CBU, MONITOR WELL. SHORT TRIP. OK. DRILL F/2201 T/2297'. CEMENTING SURFACE CASING MW: 0.0 VIS: 0 DRILL F/2297' T/3420'. CIRC HI-LOW SWEEP AROUND, MONITOR FLOW, PUMP PILL. POOH T/JARS. RIH TAG BRIDGE. CIRC & MONITOR WELL. POOH, LD BHA. OK. PU CASING TOOL, RU INJECTION LINE TO J-13. RIH 9-5/8", SHOE @ 3390'. RU CEMENTING HEAD. CIRC. CEMENTING. PU BHA #2 MW: 0.0 VIS: 0 CEMENT JOB, TEST LINES, DROPPED TOP PLUG, BLED OFF FLOATS. OK. LD LANDING JT AND ND DIVERTER SYSTEM. RU & PUMP TOP JOB. RD HALLIBURTON. NU GEN V WELLHEAD & TEST. NU BOPE. CHANGE OUT BAILS. INSTALL TEST PLUG & TESP BOPE. BOBBY FOSTER WITH AOGCC WAIVED WITNESSING TEST. ONE CHOKE VALVE FAILED & BOTH IBOP FAILED. REPAIR CHOKE VALVE & BOTH IBOP VALVES. RETEST VALVES, PULL TEST PLUG & INSTALL WEAR RING. PU BHA #2. PU BIT, MOTOR & ORIENT MWD. LOAD LWD TOOLS. TIH MW: 0.0 VIS: 0 FINISH MU BHA #2. TIH TO FLOAT COLLAR. PU DP. TEST CASING. OK. DRILL FLOAT COLLAR, CEMENT, FLOAT SHOE & 10' NEW FORMATION T/3430'. CIRC HOLE CLEAN. DRILL 8-1/2" HOLE F/3430' T/5548'. CBU. MONITOR WELL & PUMP PILL. SHORT TRIP TO CASING SHOE. OK. SERVICE TOP DRIVE & CHANGE OUT BAILS. TIH & PU DP. NOV 05 ]995 Oil & Gas Cons. Anchorage WELL ' MPJ-19 OPERATION: RIG · NABORS 22E PAGE: 2 10/21/95 ( 7) TD: 7649' (2101) 10/22/95 ( 8) TD: 9935'(2286) 10/23/95 (9) TD:l1550' (1615) 10/24/95 (10) TD:12960' (1410) 10/25/95 (11) TD:13087' ( 127) 10/26/95 (12) TD:13087' ( 0) 10/27/95 (13) TD:13087' ( 0) DRILLING 8-1/2" HOLE MW: 0.0 VIS: 0 FINISH TIH. NO HOLE FILL. RU ATLAS & GYRODATA. RUN GYRO F/5200' T/3200'. CHANGE BAILS. DRILL & SURVEY 8-1/2" HOLE F/5548' T/7649'. DRILLING 8-1/2" HOLE MW: 0.0 VIS: 0 DRILL & SURVEY 8-1/2" HOLE F/7649' T/8506'. FINISH PUMPING HI-LO SWEEP AROUND & MONITOR WELL. SHORT TRIP T/5500'. OK. PU DP & TIH. OK. DRILL & SURVEY 8-1/2" HOLE F/8506' T/9935'. DRILLING 8-1/2" HOLE MW: 0.0 VIS: 0 DRILL & SURVEY 8-1/2" HOLE F/9935' T/11267'. CIRC SWEEP AROUND. MONITOR WELL & PUMP PILL. POOH TO CASING SHOE. WORK THRU TIGHT SPOTS, SLIP & CUT DRILLING LINE, SERVICE TOP DRIVE. TIH. OK. REAM LAST STAND TO BOTTOM. NO FILL. DRILL & SURVEY 8-1/2" HOLE F/11267' T/11550'. DRILLING 8-1/2" HOLE MW: 0.0 VIS: 0 DRILL & SURVEY 8-1/2" HOLE F/11550' T/12495' FINISH CIRC SWEEP AROUND & CBU. MONITOR WELL. PUMP PILL. SHORT TRIP. OK. DRILL & SURVEY 8-1/2" HOLE F/12495' T/12960' TIH TO SET CEMENT PLUGS MW: 0.0 VIS: 0 DRILL & SURVEY 8-1/2" HOLE F/12960' T/13087' BIT. QUIT. POOH T/5850'. MAKE PASS ACROSS SANDS. POOH TO BHA. DOWNLOAD SOURCE & LD CDN, MWD, CDR, LC & STAB.SERVICE WEAR RING & CHANGE OUT BAILS. MU MULE SHOE & TIH TO SET CEMENT PLUGS. WOC MW: 0.0 VIS: 0 TIH T/13080'. CBU. MIX & SPOT CEMENT. BALANCED PLUG F/13080' T/12590'. POOH T/12130' CIRC OUT CONTAMINATED CEMENT. POOH T/6390'. CBU. MIX & SPOT CEMENT. BALANCED PLUG F/6390' T/5490'. POOH T/5400'. CIRC OUT CONTAMINATED CEMENT. MIX & SPOT CEMENT. BALANCED PLUG F/5450"'-T/4500'. POOH T/4300'. CIRC OUT CONTAMINATED CEMENT. SET STORM PACKER & WR. TEST BOPE. JOHN SPAULDING WITH AOGCC WAIVED WITNESSING TEST. PULL STORM PACKER, INSTALL WR, SERVICE TOP DRIVE, SLIP & CUT DRILL LINE, CIRC & COND MUD WHILE WAITING ON CEMENT. TIH TO SIDETRACK MW: 0.0 VIS: 0 WOC. TIH, TAG CEMENT AT 4410'. JOHN SPAULDING W/AOGCC WAIVED WITNESSING TAGGING OF CEMENT. CBU, MIX AND PUMP CEMENT BALANCED PLUG FROM 4290' TO 3600'.. POOH TO CASING SHOE, CBU. POOH, WOC. BHA #3, TIH, WASH DOWN FROM CASING SHOE TO 3628'. TAGGED SOFT CEMENT. WASH CEMENT FROM 3628' TO 3725'. CIRC AND COND MUD. POOH, MU BHA #4. ORIENT AND TEST MWD, TIH TO SIDETRACK. Gas Cons. Anchorage BOB MAGOS, INCORPORATED P.O. BOX 90006 LAFAYATT~-, LA 70509 (318)-237-9152 .. DIRECTIONAL DRTT,T.RR: BOB M~OS Curvature Calculations Gas Cons. SURVEY MEASURED COURSE NUKBER DEPTH LENGTtl 0 112 0 1 205 93 2 305 100 3 405 100 4 505 100 5 605 100 6 705 100 7 805 100 8 855 5O 9 955 100 10 1005 50 11 1055 50 12 1105 50 TRUE SUB-SEA DRIFT DR!i~T VERTICAL V~RTICAL AN~r.R DIRECTION DEPTH DEPTH 0.00 0.00 112.00 46.60 .36 4.60 205.00 139.60 .44 353.63 305.00 239.60 .64 26.94 404.99 339.59 .93 326.77 504.98 439.58 VERTICAL SECTION 0.00 · 15 .56 .89 1.72 2.24 297.19 604.95 539.55 4.41 3.97 294.03 704.79 639.39 9.75 5.74 291.49 804.43 739.03 18.01 7.25 291.25 854.1! 788.71' 23.51 9.49 284.80 953.04 887.64 37.39 10.65 284.94 1002.27 936.87 45.60 12.00 280.47 !051.30 985.90 54.68 13.80 279.03 !100.03 1034.63 64.78 N/$ E/W DLS 0.00 0.00 0'.00 .29 N .02 ~ .39 .99 N .01 E .11 1.87 N .22 E .36 3.04 N 0.03 E .83 4.61 N 2.16 W 1.50 6.92 N 7.06 W, 1.74 10.16 N 14.87 W . 1.78 12.22 N 20.14 W 3.02 16.61 N 33.99 W 2.42 18.86 N 42.44 W 2.32 20.99 N 52.02 W 3.22 22.87 N 63.02 W 3.66 !- ) ) . · . · PRUD~OE BAY DRILLING WELT.: MPJ- 19 [GYRO/MWD] SURVEY MEASURED COURSE DRIFT DRIFT NUMBER DEPTH LENGTH ANGLE DIRECTION 13 1155 5O 14 1205 50 15 1255 50 16 1305 50 17 1355 50 18 1405 50 19 1455 50 20 1505 50 21 1555 50 22 I605 50 23 1655 50 24 1705 50 25 1755 50 26 1805 50 27 1855 50' 28 1905 50 29 1955 50 30 2005 50 3i 2055 50 32 2105 50 33 2155 50 34 2205 50 35 2255 50 36 2305 50 37 2355 50 14.92 16.87 18.83 21.26 23.54 24.69 25.39 25.78 27.45 28.15 29.81 30.44 31.54 32.72 33.47 34.98 35.41 36.05 37.67 38.61 39.79 41.00 42.71 44.33 45.44 278.29 276.22 274.35 274.32 271.52 271.01 271.0! 270.88 273.04 271.19 274.96 272.52 272.71 273.70 274.71 . 276.89 277.33 278.60 280.58 282.21 283.00 284.82 287.40 288.38 289.55 TRUE VERTICAL DEPTH 1148.47 1196.56 1244.15 1291.11 1337.34 1382.98 .1428.28 1473.37 15 ].8.07 1562.30 1606.05 1649.29 1692.16 17 34.50 1776.39 1817.73 1858.59 . 1899.18 '1939.18 1978.51 2017.26 2055.33 2092.58 2128.83 2164.26 SUB-SEA VERTICAL DEPTH 1083.07 1131.16 1178.75 1225.71 1271.94 1317.58 1362.88 1407.97 '-.452.67 1496.90 1540.65 1583.89 1626.76 166p.lO 1710.99 1752.33 1793.19 1833.78 1873.78 1913.11 1951'.85 1989.93 2027 .I8 2063.43 2098.86 NOV 0,5 1995 -, ~,~sk~ C~i .& Gas Cons. Coa..:~ "~nchoraga VERTICAL SECTION N/S 75.90. 24.74 N 75.28 W 88.02 26.45 N 88.86 W 101.34 27.85 N 104.12 W 116.10 29.14 N 121.21 W 132.24 30..09 N 140.24 W 149.25 30.54 N 160.66 W 166.82 30.91 N 181.82 W 184.73 31.27 N 203.41 W 203.54 32.05 N 225.79 W 223.14 32.90 N 249.09 W 243.72, 34.22 N 273.27 W 265.19 35.85 N 298.30 W 286.96 37.03 N 324.02 W 309,59 38.52 N 350.57 W 333.07 40.53 N 377.80 W 357.64 43.38 N 405.77 383.14 46.94 R 434.36 409~17 50.99'N 463.28 436.29 56.00 N 492.85 464.61 62.10 N 523.11 493.85 69.00 N 553.95 524.10 76.80 N 585.40 555.69 86.06 N 617.44 588.61 96.64 N 650.20 622.54 108.11 N 683.57 Page DLS 2.27 4.06 4.08 4.86 5.03 2.34 1.40 .79 3.86 2.22 4.93 2 2.21 2.58 1.86 3.89 1.00 1.96 4.02 2.75 2.56 3.38 4.85 3.51 2.77 ?RUDHOE BAY DRILLING WELL: MPJ-19 [GYR0/MW1)] SURVEY MF, JtSURE D COURSE DRIFT DRIFT NU~J3ER DEPTH LENGTH ANGLE DIRECTION 38 2405 39 2455 40 2505 41 2555 42 2605 43 2655 44 2705 45 2755 46 2805 47 2905 50 50 5O 50 50 50 50 50 50 100 48 3005 100 49 3105 100 50 3205 100 51 3305 100 52 3405 100 53 35O5 100 54 3605 100 55 3705 100 56 3805 100 57 3905 100 58 4005 100 59 4105 100 60 4205 100 6! 4305 100 62 4405 I00 47,14 48.37 50,94 51.59 53.43 54.26 55.59 56.73 57.94 59.53 60.48 62.97 65.45 64.31 62.24 59.92 60.64 60.63 61.58 62.57 63.71 65.2O 64.48 63.47 65,30 290.97 291.63 294.16 294,62 297,63 297.18 301.18 300.74 303.15 302.22 302.44 301.87 304,98 305,54 305,88 307.46 306.96 307.18 305.48 306.82 305.31 304.98 304.41 303.95 304.44 TRUE VERTICAL DEPTH 2198.81 2232.43 2264.79 2296,08 2326,51 2356.01 2384.75 2412,60 2439,58 2491.48 2541,48 2588,84 2632.35 2674.81 2719.77 2768.13 2817.71 2866.75 2915.07 2961.90 3007.08 3050.21 3092.72 3136.59 3179.83 SUB-SEA VERTICAL DEPTH 2133.41 2167.02 2199.39 2230.68 2261.11 2290.61 2319.35 2347.20 2374.19 2426 .O8 2476.08 2523.44 2566.96 2609.41 2654.38 2702.73 2752.31 2801.35 2849.67 2896.50 2941.68 2984.81 3027.32 3071.19 3114.43 NOV 05 1995 .g;;~ .a Gas Cons. Com::::.~ ~-..~'~ '. ~omge VERTZCAL SECTION N/$ Page DLS 657.51. 120.64 N 717.47 W 3.97 693.49 134.08 N 751.96 W 2.65 730,76 148.92 N 787,05 W 6.43 769.11 165.02 N 822.57 W 1,49 808.31 182.50 Il 858.17 W 6.03 848.34 201.08 N 894.01 W 889,04 221,04 N 929.72 W 930,47 242.40 N 965,34 W 972.50 264.67 N 1001.04 W 1057.91 310.83 N 1072.99 W 1144.43 357,14 N 1146.17 W 1232.39 404.01 N 1220.72 W 1322.38 453.61 N 1295.84 W 1412.92 505.88 N 1369.77 W !502.22 558,01 N 1442,29 W 1589.70 610.26 N 1512.50 W 1676.47 662.78 N 1581.66, W 1763.56 715.31 N 1651.20 W 1851.08 767.17 N 1721.73 W 1939.41 819.30 N !793.07 W 2028.60 871.81 N 1865.18 W 2118.82 923.74 N 1938.96 W 2209.33 975.26 N 2013.38 W 2299.18 1025.75 N 2087,71 W 2389,34 1076.42 N 2162.29 W .81 .07 .39 .72 .78 .97 2.54 3.74 1.25 2.09 .70 .84 .19 .77 .54 1 1.52 .89 1.09 1.88 PRUDHOE BAY DRILLING WELL: MPj-19 [GYRO/MWD] SURVEY ~_J~SURED COURSE DRIFT DRIFT NUMBER DEPT~- LENGTH ANGLE DIRECTION 63 45O5 L00 64 4535 30 65 4565 30 66 4595 30 67 4625 30 68 4655 30 69 4685 30 70 4715 30 71 4745 30 72 4775 30 73 4805 30 74 4835 30 75 4865 30 76 4895 30 77 4925 30 78 4955 30 79 4985 30 80 5015 30 81 5045 30 8:, 5075 30 83 5105 30 84 5135 30 85 5165 30 o6 5i95 3o 87 5270 75 66.91 67.18 66.91 66.92 67.08 67.28 67.10 67.44 67.48 67.21 67.87 67.49 67.13 66.79 66.67 66.07 66.43 66.43 66.09 66.16 66,38 66,26 66.19 66.55 66,97 304.15 304.36 304.29 304.52 303.91 303.67 303.62 303.66 303.94 304.13 304.27 304.41 304,50 304.27 304,38 304,55 304.46 304.37 304,44 304.34 304.14 304.01 303.34 303.87 304.39 TRUE VERTICAL DEI~TH 3220.33 3232.03 3243.73 3255.49 3267.22 3278.85 3290.48 3302.07 3313.57 3325.13 3336.59 3347.98 3359.55 3371.30 3383.15 3395.17 3407.25 3419.25 3431.33 3443.47 3455.54 3467.59 3479.69 3491.7I 3521.42 SUB-SEA VERTICAL DEPTH 3154.93 3166.63 3178.33 3190.09 3201.82 3213.45 3225.08 3236.67 3248.17 3259.73 327/.19 3282,58 3294.15 3305.90 3317,75 3329,77 3341,85 3353,85 3365.93 3378.07 3390.14 3402.19 3414.29 3426.31 3456.02 NOV 05 I995 ~.;-~ a Gas Cons. Coa','::.r'r;',_ ,,': VERTICAL SECTION N/S E/W 2480.76 2508.39 2536.0L- 2563.60 2591.22 1127.94 1143.49 1159.06 1174.66 i 1.90. !.8 2237.82 W 226B.66 W 2283.47 W 2306.24 W 2329.08 W 2618.86 2646.51 2674.18 2701.88 2729.56 1205.56 1220.88 1236.21 1251.63 1267.12 N 2352.06 N 2375.08 N 2398.11 N 2%2J..14 2444.O8 w w w W W 2757.28 2785.03 2812.71 2840.32 2867.88 2895.36 2922.82 2'950.31 2977.77 3005.21 1282.70 1298.36 1314.02 1329.61 1345.15 1360.7'0 1376.26 1391.80 1407.32 1422.81 2467.01 W 2489.93 W 2512.75 W 2535.53 w 2558.29 W Ii 2580.95 w Ii 2603.58 w, 26'26.27 W 2648.92 %; 2671.56 W 3032.67 3060.14 3087.58 3115.06 3184.23 1438.27 N 1453.66 N 1468,88 N 1484,09 N 1522.90 N 2694.26 W 2717.02 W 2739.87 W 2762.76 W 2820.02 w Page DLS ! .63 /.ii .93 ,71 1,95 ,99 .62 1.14 .87 1.07 .24 .34 .23 .34 .52 2.07 1.23 ,28 1.15 .38 .95 .56 2.06 2.0! ,85 PRUDBOE BAY DRILLING WELL: MPJ-19 [GYRO/MW-D] SURVEY MEASURED COURSE DRIFT DRIFT NUMBER DEl>TH LENGTIt ANGLE DIRECTION TRUE VERTICAL DEPTH SUB-SEA VERTICAL DEPTH NO¥ 0 6 ~-:~ & Gas Cons. Com..-.:._ .... : '" ~c~orage VERTICAL SECTION N/S z/w Page DIS 88 5365 95 89 5460 95 90 5559 98 91 5654 95 92 5696 42 67.3P, 65,96 64,53 62.75 63,75 305.94 305.46 303.75 304.97 305.24 3558.40 3596.16 3637.25 3679.69 3698.68 3493.00 3530.76 3571.85 3614.29 3633.28 3272.08' 1573.50 3359.63 1624.60 3448.73 1675.20 3534.37 1723.54 3572.05 1745.21 2891.83 W 2962.94 W 3036.27 W 3106.98 W 3137.80 W .56 .56 .15 .18 .44 93 5749 52 94 5845 95 95 5939 93 96 6034 95 97 6130 95 98 6223 92 99 6320 97 100 6414 93 101 6509 95 102 6605 95 103 6703 98 104 6798 95 105 6893 94 106 6989 96 107 7084 95 64.56 66.44 67.54 67.13 65.94 64.79 64.97 65.71 66.77 66.50 65.67 65.83 66.61 66.08 65.58 3O5.48 304.54 304.71 3O5.09 305.38 304.03 302.72 303.16 302.48 302.73 302.17 301,93 302.21 301.30' 301.89 3721.75 3761.47 3798.17 3834.93 3872.99 3911.74 3953,02 3992,23 4030.64 4068,35 4108.09 4!47,31 4185,50 4224,23 426'3.19 3656.35 3696.07 3732.97 3769.53 3807.59 3846.34 3887.62 3926.83 3965.23 4002.95 4042.69 4081.91 4120.10 4158.83 4197.79 3619.66 1772.76 3706.82 1822.76 3793.24 1871.87 3881.27 1922.23 3968,94 1972.81 4053.44 2020.93 4141.44 2069.35 4226.80 2115.80 4313.98 2163.08 4401.21 2210,12 4490.75 2258.20 4597.71 2304.41 4664.28 2350.43 4752.54 2396.95 4839.22 2442.44 N 3176.63 W N 3248.02 W N 3319.14 W N 3391.33 W N 3462.95 W N 3532.41 W N 3605.93 W N 3677.60'W N 3750.92 W N 3824,46 W 3900.08 W 3973.89 W 4047.33 W 4122.49 W 4196.44 W 1.59 2.16 1.18 .57 1.28 1.81 1.23 .89 1.29 .37 1.00 .28 .87 1.02 .77 108 7179 94 109 7275 96 110 7371 95 111 7466 95 112 7560 93 65.47 65.71 66.04 65.89 66.02 301.80 302.23 303.50 303,47 304.43 4302.18 4342.05 4381.29 4420.03 4458.08 4236.78 4276.65 4315.89 4354.63 4392.68 4924.76 2487.63 N 4269.21 W 5012.50 2534.21 N 4343.70 W 5100.04 2581.74 N 4417,28 W 5186.89 2629.67 N 4489.73 W 5272.15 2677.30 N 4560.47 W .15 .48 1.26 .16 .95 ?RUDHOE BAY DRILLING ~'E~.L: MmJ-I9 SURVEY MF~%SURED COURSE DRIFT DRIFT NUFfBER DEPTH LENGTH ANGLE DIRECTION 113 7655 95 114 7750 95 115 7846 95 116 7941 94 117 8037 96 118 8133 96 119 8228 94 120 8324 96 121 8419 94 122 8514 95 123 8609 95 124 8703 93 125 8799 96 126 8894 95 127 8990 95 128 9085 95 129 9179 94 130 9276 96 131 9371 95 132 9467 95 133 9563 .95 134 ,9657. 94 135 9752 94 136 9847 94 137 9941 94 65.86 64.94 65.11 65.90 65.9O 66.30 67.10 66.90 66.50 66.10 66.80 67.20 66.90 66.60 66.20 65.70 65.4O 65.40 65.70 65.2O 65.5O ,.66..3 0 66.80 '66.90 66.60 305.79 304.36 306.10 305.80 306.70 307.00 306.80 308.10 307.40 306.20 307,20 307,80 307,80 307,80 307.70 305,8O 307.00 303,20 303,70 302,20' 302,20 303,40... 304.50 305.60 304.20 TRUE VERTICAL DEPT8 4496.93 4536.62 4577.07 4616.43 4655.63 4694.61 4731.99 4769.62 4807.03 4845.26 4883,50 4920,03 4957.58 4995.20 5033,27 5072.24 5111.27 5151,33 5190,77 5230.62 5270.57 53.09 . 16 5346.81 5384.12 5421.46 SUB-SEA VER~C~ DEPTH 4431.53 4471.22 4511.67 4551.03 4590.23 4629.21 4666.59 4704.22 4741.63 4779.86 4818.10 4854.63 4892.18 4929.80 4967.87 5006.84 5045.87 5085.93 5125.37 5165.22 5205,17 ,524.3..,.76. 5281.41 5318.72 5356.06 NOV 05 ;99 .... ~'~ L:':; & Gas Cons, Con~.. ,_,.. ,, . 'Anchorage ' VERTICAL SECTION N/$ E/W Page DLS 5359.16 2727,34 N 4631.65 W 1.3i · 5445.85, 2777.16 N 4702.59 W 1.67 5532.69 2827.25 N 4773.52 W 1.66 5619.07 2877.97 N 4843.45 W .88 5706.67 2929.79 N 4914.13 W .86 5794,58 2982,54 N 4984.51 W .50 5881,31 3034,65 N 5053,92 W .87 5969,87 3088,55 N 5124.29 W 1.26 6056.64 3141.74 N 5192.99 W .80 6143.67 3193.90 N 5262.71 W 1.23 6231.35 3246.33 N 5333.05 W 1.21 6317.33 3298.73 N 5401.33 W .73 6405.90 3353.08 N 5471.40 W .31 6493.34 3406.75 N 5540.59 W .31 6580,38 3460,10 N 5609.49 W ,43 6667.63 3512.33 N 5679.44 W 1.89 6753.44 3563.27 N 5748.53 W 1.20 6840.89 3613.55 N 5820.07 W 3.5.9 6927.61 3661.37 N 5892.46 W .57 7014.79 3708.82'N 5965.65 W i.SL 7101.76 3755.21 N 6039.33 W .3i · 7187.97 3801.94, N ~,~..L.!.,83-.W .... 1.43 7274.74 3850.41 N 6183.383 W 1.19 7362.00 3900.52 N 6255.26 W 1.07 7448.91 3950.25 N 6326.54 W 1.40 PRUDHOE BAY DRILLING W'ELL: M]~J-19 [GYRO/MWD] SUR%q~Y MEASURED COURSE DRIFT DRIFT NUMBER DEPTB LENGTH ANGLE D I RECTI ON 94 95 95 96 95 138 10035 139 10131 140 10226 141 10322 142 10418 TRUE VERTICAL DEPT~ 66.30 303.30 5459.02 65,80 303.30 5497.87 65,90 303.50 5536.82 65,90 303.10 5576.10 65,90 303.90 5615.09 NOV 05 ]995 ,. zs_k. a.-~i~ & Gas Cons, CoJ~:::.: ~chorage ' '" "" - ~'"; ' '" '- · ': - ' 'llk,[. ' --'~' SOB-SEA VERTICAL VERTIC~ DEPTR SECTION N/S E/W 5393,62 7535.06 3998.13 N 6398.19 W 5432.47 7622,49 4046,14 N 6471.29 W 5471.42 7709,33 4093.96 N 6543,81 W 5510,70 7797.11 4142.17 N 6617,20 W 5549.69 7884.26 4190.29 N 6689.90 W Page DLS .93 .52 .22 .38 .76 143 10514 144 10609 145 10705 146 10800 147 10896 148 10991 149 11083 150 11175 151 11272 152 11367 153 11462 154 11557 155 11651 156 11744 157 11840 96 65.90 303.90 5654.33 94 65,60 305.70 5693,31 95 65.30 306.50 5733.16 95 64.70 . 305.70 5773.48 95 65.20 306.00 5814.00 94 65,80 306.10 5853,27 92 65,60 306,50 5891.2! 9! 65,10 305.30 5929.50 97 64,50 305.70 5970.93 95 62.20 305.10 6013.76 95 59,80 305.30 6059.81 94 57.80 304.80 6108.97 93 56.00 303.70 6160.14 93 54.30 304.80 6213.46 95 52.20 303.40 6270.53 5588,93 .. 7971.97 4239.22 N 6762.71 5627,91 8058.49 4288.59 g 6833,76 5667.76 8145.70 4339,99 N 6904,24 5708,08 8232.14 4390.93 N 6974.10 5748.60 8318.83 4441,71 N 7044.37 5787,87 8404.98 4492.42 N 7114.04 5825,81 8488.99 4542.17 N 7181.76 5864.10 8572.41 4591'09 N 7249~35 5905.53 8660.44 4642.21 N 7321.02 5948.36 8745.78 4691.66 N 7390.59 5994.42 8828.87 4739.55 N 7458.48 W 6043'.57 8910.04 4786.17 N 7524.93 W 6094.74' 8988.52 4830.35 N 7589.80 W 6148'06 9065.08 ' 4873.43 N 7653.09 W 6205.13 9141.50 4916,29 N 7716.37 W 0.00 1.76 .82 .99 .60 .64 .45 1.31 .72 2.47 2.53 2.15 2 .i6 2.06 2.50 158 11935 159 12030 160 12124 161 12218 162 :2313 95 94 93 94 94 50.50 304.20 6330.18 48.90 305.20 639!.56 47.2C 304.70 6454.19 45.10 304,90 6519.45 43.50 307 , i0 6587 · 15 6264,78 92!6.07 4957.77 N 7778.35 W 6326.16 9288,44 4998.97 N 7837.85 W 6388.79 9358.13 5038,89 N 7894,97 W 6454.05 9426.05 5077,66 N 7950.75 W 6521.75 9492.10 5116,47 ~ 8004.21 W .90 .86 .23 .35 CD PRUDHOE BAY DRILLING 0 ~ELL: MPJ-19 [GYRO/MHD] · · -~ ..' - ~'~. '.-~-'~. ~--...~ '.. ' .... .;.',~',....".; ' '.': .... . . ...o . . ....~ _' ' .'..' _~ .u ...... :. ...... ':. - . ' SURVEY MEASURED COURSE DRIFT NUMBER DEPTE NOV 05 i99§ ,.-..~.si~ c:~ .& Gas Cons. TRUE SUB-SEA DRIFT VERTICAL VERTICAL LENGTB ANG -LE DIRECTION DEPTH DEPTH ~RTICAL SEC"ZION N/S E/W Cn !63 12406 93 42.70 306.80 6655.42 6590.02 " "-64 12504 97 42.50 307.20 6727.19 6661.79 :65 12597 93 42.80 308.60 6795.82 6730.42 H- 166 12692 95 43.00 309.80 6865.85 6800.45 CD ~67 127B4 9 1 43.10 308.80 6932.79 6867.39 9555.94' 5154.88 N 8055.26 W 9621.89 5194.59 N 8107.96 W 9685.02 5233.42 N 8157.84 W 9749.91 5274.55 N 8208.27 W 9812.25 5314.16 N 8256.66 W 168 12879 94 43./0 307.70 7001.86 169 12973 94 42.40 309.20 7071.26 170 13000 26 42.20 308.00 7090.78 The following is a projection - 171 13087 87 42.20 308.00 7155.23 6936.46 7005.86 7025.38 9876.77 5354.17 N 8307.42 W 9940.79 5394.05 N 8357.65 W 9958.52 5405.14 N 8371.54 W 7089.83 10016.88 5441.12 N 8417.59 W Final Station Closure Distance: 10023.05 Feet; Direction: 302.88 Page 8 DLS .88 .34 .07 .88 .75 .79 1.31 3.15 0.00 OC .-~4 1995 BP EXPLORATION ENGINEERING DATA - ' -- BaPG~/AFE NO. ENGINEER ~, ~ ~a~ DE~. APP'VL DATE ~ FILE NO. AK 2337,1 (319~,) 'l:'d ~6, P~ STATE OF ALASKA AL/~,.,r,,A OIL AND GAS CONSERVATION COMMISSIL)N APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend __ Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program X Pull tubing __ Variance __ Pedorate__ Other__ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) BP Exploration (Alaska) Inc. Development x KBE = 65 Exploratory __ 3. Address Stratigraphic__ 7. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 Service__ Milne Point Unit 4. Location of well at surface 8. Well number 2234' NSL, 3301' WEL, SEC 28, T13N, RIOE At top of productive interval At effective depth ORIGINAL At total depth MPJ- 19 9. Permit number 95-159 10. APl number 50- 029-22607 11. Field/Pool Milne Point Unit / Kuparuk Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Size feet Plugs (measured) feet feet Junk (measured) feet Cemented Measured depth True vertical depth OCT '1 ~' &k3s .~ ull & Gas Cons. Commissi0.rl 13. Attachments Description summary of proposal X Detailed operations program __ BOP sketch 14. Estimated date for commencing operation October 17, 1995 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Suspended__ Service 17. I hereby ce~.that the foregping is true~apd correct to the best of my knowledge. Signed /'ct'T') Title Senior Drilling Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Co~ission so representative may witness Plug integrity_ BOP Test__ Location clearance __ Mechanical Integrity Test__ Subsequent form required lO- Original Signed By David W. Johnston Approved by order of the Commission Form 10-403 Rev 06/15/88 Date I Approva, NO.~-¥-._ ,pproved COpy Comm.ssioner Date SUBMIT IN/TRIPLICATE ewioes ri I i!i i"n g TO: FROM: DATE: Blair Wonzell, Senior Petroleum Engineer, AOGCC B. Campbell/Joe Polya October 17, 1995 SUBJECT: SUMMARY OF APPROVED CHANGES TO CASING STRING As per in-house discussions and subsequent approval, MPJ-19 is now planned to be a Ultra Slim Hole 7" long string well into the Kuparuk Reservoir. Running 7" to TD would obviously negate the need for the 5" liner which was originally planned for and submitted on the APD. Evaluation has shown that a long string design will in no way jeopardize well integrity. This is based to a large extent on the reasoning behind "shallow setting" the 9-5/8" surface casing, which is: I. Pore Pressure Issues on MPJ-09 are manageable with Shallow Set Surface Casing: , We are running an IHR Gyro on this well to reduce the error of ellipse and ensure we do not cross over into the MPJ-09 fault. . The MPL-17 Kuparuk producer which is in the same fault block as the MPJ-19 target is at normal reservoir pressure 3500 psig (9.6 ppg). , In the very unlikely event that we do cross this Southeast fault, the highest expected reservoir pressure given the volume injected into the MPJ-09 well and the material balance for a fault this large is 10.9 ppg. . The kick tolerance for the 10.9 ppg reservoir case with an 11.4 ppg mud to balance (0.5 ppg trip margin) is 83 barrels with shallow surface casing set at 3400' md (2730' tvd). The kick tolerance for a deep surface casing set below the Schrader Bluff Sands at 6700' md (4082' tvd) is 116 bbls. Note: These kick toierances are based on a 0.39 psi/ft influx gradient based on the 600 GOR Kuparuk crude. ACTION ITEM: 1. Based on the foregoing, an "Application for Sundry Approvals" will be made- up immediately and submitted to AOGCC for approval listing the following changes from the original APD: a) No 5" liner will be run; b) 7" casing will be run to proposed TD at +/- 13456'. B. Campbell/J. Polya 0CT 'i ( 1995 Gas Cons. Commissiori I Well Name: [ MPJ-19 I Well Plan Summary Type of Well (producer or injector): I Kuparuk Producer I Surface Location: 2334 NSL 3301 WEL Sec 28 T13N R10E UM., AK. Target Location: 2290 NSL 1244 WEL Sec 19 T13N R10E UM., AK. Bottom Hole Location: 2446 NSL 1480 WEL Sec 19 T13N R10E UM., AK. I AFE Number: I 330168 ] [ Estimated Start Date: I 10/15/95 I I Rig: I Nabors 22-E ] Operating days to complete: [ 15 IMD: I13456. I I TVD: 17392' bkb I ]KBE: 165' Well Design (conventional, slimhole, etc.): I Milne Point Ultra Slimhole 7LS Formation Markers: Formation Tops MD TVD (bkb) base permafrost 1961 1864 NA 5999 3795 Top of Schrader Bluff Sands (8.3 ppg) Seabee Shale 6585 4035 Base of Schrader Bluff Sands (8.3 ppg) HRZ 12248 6483 High Resistivity Zone Top Kuparuk 12845 6925 Kuparuk Cap Rock Target Sand -Target 13015 7054 Target Sand (9.9 ppg) Total Depth 13456 7392 Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MDfrVD 24" 20" 91.14/ H-40 Weld 80 32/32 112/112 12 1/4" 9 5/8" 404/ L-80 btrc 3369 31/31 3400/273C 8 1/2" 7" 264/ L-80 btrc 13426 30/30 13456/739: Internal yield pressure of the 7" 264/casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 7000 TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3998 psi is 3301 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: Open Hole Logs: Surface Intermediate Final Cased Hole Logs: MWD Directional DSS N/A 1. PDC Bit f/Prince Creek to TD w/MWD Dir and LWD (GR/CDR/CDN). Mudloggers are NOT required for this well. oCT Gas Cons. Commission Mud Program: I Special design considerations I None- SPUD MUD Surface Mud Properties: [ Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 100 15 8 10 9 8 to to to to to to to 9.0 50 35 15 30 10 15 Intermediate Mud Properties: N/A I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Production Mud Properties: I None- LSND freshwater mud Density Marsh Yield 10 sec 10 rain pH Fluid (PP G) Viscosity Point gel gel Loss 9.0 40 10 3 7 8.5 6-8 to to to to to to to 10.4 50 15 10 20 9.5 4-6 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: I IS00' [ Maximum Hole Angle: I Close Approach Well: 66° I (No Shut Ins) Disposal: Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. Request to AOGCC for Annular Pumping Approval for MPJ-19: 1. Approval is requested for Annular Pumping into the MPJ-19 and MPJ-13 9-5/8" x 7" casing annuli. 2. Aquifers in the Milne Point Unit have been exempted from Class II injection activities by the AOGCC by Aquifer Exemption Order #2 as referenced in Area Injection Order #10. There are no domestic or industrial use water wells located within one mile of the project area. 3. The 9-5/8" casing shoe will be set at 3400' md (2730' tvd) which is a minimum of 500' tvd below the Permafrost and into the Prince Creek formation which has a long established history of annular pumping at Milne Point. 4. The burst rating (80%) for the 9-5/8" 40# LB0 casing is 4600 psig while the collapse rating (80%) of the 7" 26# L80 casing is 4325 psig. The break down pressure of the Prince Creek formation is 13.5 ppg equivalent mud weight. The Maximum Allowable Surface Pressure while annular pumping is calculated according to the following equation and is 3100 psi for a 10.4 ppg fluid in this well (Assumes worst case in which 7" casing is filled with gas). MASP = 4325 psig - ((fluid density ppg - 1.9) X 0.052 X 9-5/8" Casing Shoe TVD 5. A determination has been made that the pumping operation will not endanger the integrity of the well being drilled by the submission of data to AOGCC on 7/24/95 which demonstrates the confining layers, porosity, and permeability of the injection zone. 6. The cement design for this well ensures that annular pumping into hydrocarbon zones will not occur. AREA WELL PREV VOL PERMITTED PERMITTED INJECTED VOL DATES (aBES) (aBES) Milne Point MPJ-13 1220 0 1995 Milne Point MPJ-19 0 0_ ..... ,.19~ DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. 0CT t 1995 Naska u~t & Gas Cons. C0mmissi0r~ An0h0rage . 2. 3. 4. 5. . . 10. 11. 12. 13. 14. 15. 16. MPJ-19 Proposed Summary of Operations Drill and Set 20" Conductor. Weld a starting head and top job nipple on conductor. Prepare location for rig move. MIRU Nabors 22E drilling rig. NU and test 20" Diverter system. Build Spud Mud. Drill a 12-1/4" surface hole as per directional plan and run and cement 9-5/8" casing. Run only Dir MWD. ND 20" Diverter, NU and Test 13-5/8" BOPE. MU a on a PDC bit on a motor, with Directional MWD and LWD CDR/CDN (GR/RES/Dens/Neu). RIH, Drill out FE and 10' of new formation -- Perform FIT to 12.5 PPg. Drill 8.5" hole to TD as per directional plan -- Run and Cement 7" Casing. RIH while PU 3-1/2" drill pipe and tandem 7" 26# scrapers and bit. Drill the ES Cementer and RIH to PBTD, perform a casing wash while displacing the hole with source water. Filter source water to 2 micron absolute. Freeze Protect Top 2000' of hole with diesel. Pressure test above the plug to 3500 psig. POOH LD remainder of 3-1/2" drill pipe. ND BOPE, NU and Test Tree. RDMO Nabors 22E drilling rig to drill next well. Perforate and Stimulate in absence of rig. Displace well with 10.2 ppg brine and set a wireline retrievable bridge plug. MIRU Nabors 4ES or Polar 1 Rig. NU & Test BOPE to 5000 psig. Perform Casing Wash. Change Rams and run Electric Submersible Pump on 2-7/8" threaded tubing. Install Surface Lines and Wellhouse and put the well on production. Drilling Hazards and Risks: . . The Kuparuk reservoir sands are over pressured to 12.7 ppg in the MPJ-09 injector which is located two faults and 7920 feet away from the MPJ-19 location. Reservoir bulk volume calculations indicate the highest possible pressure adjacent the fault line is 10.9 ppg EMW. The MPL-17 kuparuk producer is in the same fault block as the MPJ-19 target and shows reservoir pressure at virgin (3500 psig or 9.6 ppg). An IHR Gyro will be run in the first 1500' out of the surface casing shoe to ensure that we do not drill cross the fault line into the possible MPJ-09 pressure. In the unlikely e'vent MPJ-Ofi fault is crosseo; the &dck tolerance for the 10.9 ppg pore pressure case with 11.4 ppg mud weight is 83 bbls. This is calculated using a 0.39 psi/ft gas gradient for the Milne Point Kuparuk Crude with a 600 GOR. Discuss the MPJ-09 pressure status and this kick tolerance at the pre-reservoir meeting before drilling into the Kuparuk reservoir -- and perform a Flow Check after penetratin~l each of the Kuparuk A3, A2, and A1 sands. Gas hydrates: Although hydrates were encountered on E, H, and Pads, it is evident from the neutron/density crossplots of MPJ-01 and from 6 wells drilled by Nabors 22E in 1994 that hydrates are not present on J Pad. However, in the event hydrates are encountered follow the guidelines outlined on the MPI Pad Data Sheet -- these should be updated when we receive an Updated MPJ-Pad Data sheet. 4. No other drilling hazzards or risks have been identified for this well. CASING SIZE: 9-5/8" MPJ-19 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CIRC. TEMP 50 deg F at 2500' TVDSS. SPACER- 75 bbls fresh water. LEAD CEMENT TYPE: ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX #SACKS: 674 Type E Permafrost YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE: ADDITIVES: 2.0% CaCI2 WEIGHT: 15.8 ppg APPROX #SACKS: 250 FLUID LOSS: 100-150 cc Premium G YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. FREE WATER: 0 TOP JOB CEMENT TYPE: Permafrost E ADDITIVES: Retarder WEIGHT: 12.0 ppg gal/sk APPROX NO SACKS: 150 YIELD:2.17 ft3/sx MIX WATER: 11.63 4. Top CENTRALIZER PLACEMENT: 1. 1 Bowspring centralizer per joint of 9-5/8" casing on bottom 15 joints of casing (15 required). 2. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacedmud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Mix slurry on the fly-- batch mixing is not necessary. CEMENT VOLUME: 1. The Tail Slurry volume is calculated to cover 618' md above the 9-5/8" Casing Shoe with 30% excess. 2. The Lead Slur .ry volume is calculated to cover from the top of the Tail Slurry to 1500' md with 30% excess and from 1500' md to surface with 100% excess. 3. 80'md 9-5/8", 40# capacity for float joints. Job Cement Volume is 150 sacks. MPJ-19 Well 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON STAGE I CEMENT JOB ACROSS THE KUPARUK INTERVAL: CIRC. TEMP: SPACER: 140° F BHST 170 deg F at 7040' TVDSS. 20 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1 above current mud weight. CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk APPROX # SACKS: 222 FLUID LOSS: < 50cc/30 min @ 140° F MIX WATER: 5.0 gal/s THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F FREE WATER: 0cc @ 45 degree angle. STAGE II CEMENT JOB ACROSS THE SCHRADER BLUFF SANDS: CIRC. TEMP: 60°F BHST 80° F at 7040' TVDSS. SPACER: 20bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1 above current mud weight. LEAD CEMENT TYPE: ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX #SACKS: NONE Type E Permafrost YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.2% Halad 344 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk APPROX # SACKS: 244 ~,, FLUID LOSS: 100-150 cc THICKENING TIME: 4 hours @ 50 FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7" x 8-1/4" Straight Blade Rigid Centralizers-- two per joint on the bottom 18 joints of 7" (36 total). This will cover 300' above the C1 Sand. 2. Run ""'" 7" ¢ '/,~,,o.,.-.=.,~,, B'a;:-* "'-'--; ' ' : ....... · ..,,,.. x ~-;,.-, ,.,,, ~,~j, ,, , .~= m,9,d C. entrahzer~,u"~'-."'"-.,,, and De,uw :lie ;' ES Ceme Total). 3. 7" x 8-1/4"Straight Blade Rigid Centralizers-- two per joint from OB Base Sand to 200' above Sand (44Total). 4. Run two 7" x 8-1/4"Straight Blade Rigid Centralizer inside the 9-5/8" casing shoe. 5. Total 7"x 8-1/4"Straight Blade Rigid Centralizers needed is 84. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud progra ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to p~ job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. CEMENT VOLUME: 1. Stage 1 cement volume is calculated to cover 1000' md above the Kuparuk Target Sand wi excess. 2. Stage 2 cement volume is calculated to cover from the OB Base to 1000' above the NA Top with 30% excess. STATE OF ALASKA REVISION- 10/13/95 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type ofwork Drill I~ Redrill[~llb. Type ofwelI. Exploratory[] Stratigraphic Testl-] DevelopmentOilE] Re-Entry [] DeepenI'-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 65 feet Milne Point / Kuparuk River 3. Address 6. Property Designation P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025515 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 ^AC 25.025) 2234' NSL, 3301' WEL, SEC 28, T13N, RIOE Milne Point Unit At top of productive interval 8. Well number Number 2290' NSL, 1244' WEL, SEC 19, T13N, RIOE MPJ-19 (Name Change; was MPJ-18) 2S100302630-277 At total depth 9. Approximate spud date Amount 2405'NSL, 1422' WEL, SEC 19, T13N, RIOE 10/14/95 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in propertyi15. Proposed depth (MD and TVD) property line ADL 025517 2405 feet No Close Approach feet 2544 13456'MD/7392' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 500 feet Maximum hole angle 66 o !Maximum surface 4291 psig At total depth (TVD) 6857'/5000 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 3369' 31' 31' 3400' 2730' 526 sx PF 'E', 250 'G', 250 PF 'E' 8-1/2" 7" 26# L-80 Btrc 12870' 30' 30' 12900' 6966' 155 sx Class 'G', 159 sx Class 'G' 6" 5" 15# L-80 FL4S 706' 12750' 6851' 13456' 7392' 128 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor ~-. ~. ~ ~ i~ Surface iL.~ , -"' Intermediate .... , Production oCT i ..., t':;~ '~. :J Liner Perforation depth: measured ~l~S_~t~..U~.& Gas O0i'~s. true vertical ,. Anchorage 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] !Drilling fluid program [] Time vs depth plot [] Refraction analysis i-I Seabed reportl-I 20 AAC 25.050 requirements[] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~--"~- "~'~'-~-'"~-'~'--~"~.~--~ Title Senior Drillin~ Engineer Date Commission Use Only Permit Number IAPI number Approval date See cover letter ~7'.~",.- ,,,/,.~' ]50-~---~" .~----~--~/"~,~ I /~ -..-/.,_~. ¢,...,~~' for other requirements Conditions of'approval Samples required [] Yes [] No Mud Icg required []Yes ~ No Hydrogen sulfide measures [] Yes ~ No Directional survey required · ~ Yes [] NO Required working pressure for BOPE []2M; F13M; I-ISM; I-]10M; 1-'115M; Other: Original Signea By by order of Approved by David W. Johnston Commissioner tne commission Date Form 10-401 Rev. 12-1-85 Submit in triplicate Well Name: ] MPJ-19 Well Plan Summary I Type of Well (producer or injector): ]Kuparuk Producer I Surface Location: 2234 NSL 3301 WEL Sec 28 T13N R10E UM., AK. Target Location: 2290 NSL 1244 WEL Sec 19 T13N R10E UM., AK. Bottom Hole Location: 2446 NSL 1480 WEL Sec 19 T13N R10E UM., AK. I AFE Number: I 330168 ] I Estimated Start Date: 110/14/95 I IMD: I 13456' I ITVD: I Well Design (conventional, slimhole, etc.): I Rig: I Nabors 22-E I Operating days to complete: I 1 0 I 7392' bkbI I Milne Point Ultra Slimhole-5" liner 165' Formation Markers: Formation Tops MD TVD (bkb) base permafrost 1961 1864 NA 5999 3795 Top of Schrader Bluff Sands (8.3 ppg) OB Seabee Shale 6585 4035 Base of Schrader Bluff Sands (8.3 ppg) HRZ 12248 6483 High Resistivity Zone Top Kup 12845 6925 Kuparuk Cap Rock [~ '.., ~ ~ ~ Kuparuk Target Sand 13015 7054 Target Sand (13.6 ppg) Total Depth 13456 7392 Casing/Tubing Program: A~asCa Oil & Gas Cons. C0rnmissi0n Ag~h0rafl¢ Hole Size Csg/ Wt/Ft Grade Conn Length Top .... "--Btlll Tbg O.D. MD/TVD MD/TVD 24" 20" 91.1# H-40 Weld 80 32/32 112/112 12 1/4" 9 5/8" 40# L-80 btrc 3369 31/31 3400/273( 8 1/2" 7" 26# L-80 btrc 12870 30/30 12900/696 6" 5" 15# L-80 FL4S 706 12750/6851 13456/739 Internal yield pressure 'of the 7" 26# casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 6857' TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 5000 psi is 4291 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: Open Hole Logs: Surface MWD Directional DSS Intermediate MWD Dir and LWD CDR (GR/RES) Final Cased Hole Logs: Insert Bit to TD w/MWD Dir and LWD (GR/RES -- Wireline Triple Combo Back-up). Mudloggers are NOT required on this well. Mud Program: ] Special design considerations I None- SPUD MUD Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 50 15 8 10 9 8 to to to to to to to 9.0 100 35 15 30 10 15 Intermediate Mud Properties: N/A I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Production Mud Properties: I None- LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 40 10 3 7 8.5 6-8 to to to to to to to 10.4 50 15 10 20 9.5 4-6 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: I OV: 15oo' IMaximum Hole Angle: Close Approach Well: 66 (No Shut Ins) I OCT i995 1 h aska 0il & Cons. Commission Anchorage Disposal: Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. Fluid Handling: MPJ-13 is available for annular injection. Request to AOGCC for Annular Pumping Approval for MPJ-19: 1. Approval is requested for Annular Pumping into the MPJ-19 and MPJ-13 9-5/8" x 7" casing annulii.' 2. Aquifers in the Milne Point Unit have been exempted from Class II injection activities by the AOGCC by Aquifer Exemption Order #2 as referenced in Area Injection Order #10. There are no domestic or industrial use water wells located within one mile of the project area. 3. The 9-5/8" casing shoe will be set at 2700' md (2505' tvd) which is a minimum of 500' tvd below the Permafrost and into the Prince Creek formation which has a long established history of annular pumping at Milne Point. 4. The burst rating (80%) for the 9-5/8" 40# L80 casing is 4600 psig while the collapse rating (80%) of the 7" 26# L80 casing is 4325 psig. The break down pressure of the Seabee formation is 13.5 ppg equivalent mud weight. The Maximum Allowable Surface Pressure while annular pumping is calculated according to the following equation and is 3200 psi for a 10.4 ppg fluid in this well (Assumes worst case in which 7" casing is filled with gas). MASP - 4325 psig - ((fluid density ppg - 1.9) X 0.052 X 9-5/8" Casing Shoe TVD 5. A determination has been made that the pumping operation will not endanger the integrity of the well being drilled by the submission of data to AOGCC on 7/24/95 which demonstrates the confining layers, porosity, and permeability of the injection zone. 6. The cement design for this well ensures that annular pumping into hydrocarbon zones will not occur. AREA .WELL PREV VOL PERMITTED PERMITTED INJECTED VOL DATES (aBES) (aBES) Milne Point MPJ-13 1 220 0 1 995 Milne Point MPJ-19 0 0 1995 DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. MPJ-19 Proposed Summary of Operations 1. Drill and Set 20" Conductor. Weld a starting head on conductor. 2. Prepare location for rig move. 3. MIRU Nabors 22E drilling rig. 4. NU and test 20" Diverter system. Build Spud Mud. 5. MU 12-1/4" bit and MWD (Dir), drill surface hole, and run and cement 9-5/8" casing. 6. ND 20" Diverter, NU and Test 13-5/8" BOPE. 7. RIH w/PDC bit on a motor with MWD and CDR/CDN), Test 9-5/8" casing to 3000 psig for 30 minutes, Drill out float equipment and 10 feet of new formation, Perform a FIT -- 12.5ppg. 8. Drill 8.5" hole to +100' tvd above the To Kuparuk Sand, POOH, and LD the PDC bit and 7Stage Motor. 9. Wiper Trip, POOH and LD BHA, Change Top Rams to 7", and Run and Cement 7" casing, Bump the plug, check the floats, and pressure test the casing to 3500 psig for 30 minutes. 1 0. MU the 6" bit and Sperry LWD (Recorded GR and RES) drill to TD. Wiper Trip to the 7" casing shoe. Drop Rabbit and POOH. 1 1. RU and Run the 5" liner on 3-1/2" drill pipe. Cement 5" Liner. 12. RIH with 6" bit and scraper to clean off the Top of the 5" liner top packer. POOH. 1 3. RIH with 4.25" mill and clean out the liner to the landing collar. Test Casing to 4500 psig for 30 minutes. Displace drilling mud with source water with 25 gal/100bbl Corexit and filter. 14. POOH while LD 3-1/2" Drill Pipe -- Freeze Protect Well while POOH. 15. ND BOPE & NU the False Bowl. NU and test the Dry Hole Tree to Prepare Well for Running Completion with 4ES or Polar I at a later date. 16. RDMO Nabors 22E drilling rig to drill next well. Drilling Hazards and Risks: 1. The Kuparuk A Sand is over pressured to 13.5 ppg and a liner will be set 100' tvd above this sand. 2. Hydrates have not been experienced in the 13 wells that have been drilled on this pad; however, be prepared to follow the Hydrate guidelines as outlined on the pad data sheet. 3. No other drilling hazzards or risks have been identified for this well. CASING SIZE: 9-5/8" MPJ-19 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CIRC. TEMP 50 deg F at 2500' TVDSS. SPACER: 75 bbls fresh water. LEAD CEMENT TYPE- ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX #SACKS: 526 Type E Permafrost YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE: ADDITIVES: .2.0% CaCI2 WEIGHT: 15.8 ppg APPROX #SACKS: 250 FLUID LOSS: 100-150 cc Premium G YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. FREE WATER:0 TOP JOB CEMENT TYPE: Permafrost E ADDITIVES: Retarder WEIGHT: 12.0 ppg gal/sk APPROX NO SACKS:250 YIELD:2.17 ft3/sx MIX WATER: 11.63 CENTRALIZER PLACEMENT: 1. 1 Bowspring centralizer per joint of 9-5/8" casing on bottom 15 joints of casing (15 required). 2. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Mix slurry on the fly-- batch mixing is not necessary. CEMENT VOLUME: 1. The Tail Slurry volume is calculated to cover 618' md above the 9-5/8" Casing Shoe with 30% excess. 2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry to 1500' md with 30% excess and from 1500' md to surface with 100% excess. 3. 80'md 9~5/8", 40# capacity for float joints. 4. Top Job Cement Volume is 250 sacks. STAGE I MPJ-19 Well 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON CEMENT JOB ACROSS THE KUPARUK INTERVAL' CIRC. TEMP: SPACER' 140° F BHST 170 deg F at 7040' TVDSS. 20 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1 above current mud weight. CEMENT TYPE' Premium G ADDITIVES: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 WEIGHT: 15.8Ppg YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/s APPROX # SACKS: 155 THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F FLUID LOSS: < 50cc/30 min @ 140° F FREE WATER: 0cc @ 45 degree angle. STAGE II CEMENT JOB ACROSS THE SCHRADER BLUFF SANDS CIRC. TEMP' 60o F BHST 80 deg F at 7040' TVDSS. SPACER: 20bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1 above current mud weight. LEAD CEMENT TYPE: ADDITIVES: Retarder WEIGHT: 12.0'ppg APPROX #SACKS: NONE Type E Permafrost YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.2% Halad 344 WEIGHT: 15.8ppg APPROX # SACKS: 159 FLUID LOSS: 100~150 cc YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk THICKENING TIME: 4 hours @ 50 FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7" x 8-1/4" Straight Blade Rigid Centralizers-- one per joint on the bottom 10 joints of 7" (10 total). 3. Run one 7" x 8-1/4"Straight Blade Rigid Centralizer above and below the 7" ES Ceme Total). 2. 7" x 8-1/4"Straight Blade Rigid Centralizers-- two per joint from OB Base Sand to 200' above Sand (26 Total). 3. Run two 7" x 8-1/4"Straight Blade Rigid Centralizer inside the 9-5/8" casing shoe. 4. Total 7" x 8-1/4"Straight Blade Rigid Centralizers needed is 40. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud progra ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to p~ job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. CEMENT VOLUME' 1. Stage 1 cement volume is calculated to cover 1000' md above the 7" casing shoe with 30% 2. Stage 2 cement volume is calculated to cover from the OB base to 500' above the NA Top with 30% excess. Anchorage MPJ-19 5" PRODUCTION CEMENT PROGRAM- LINER HALLIBURTON CIRC. TEMP: 140°F BHST 170 deg F at 7040' TVDSS. SPACER: 20 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications . weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 WEIGHT: 15.8ppg gal/sk YIELD: 1.15 cu ft/sk MIX WATER: 5.0 APPROX # SACKS: 128 THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F FLUID LOSS: < 50cc/30 min @ 140° F angle. FREE WATER: 0cc @ 45 degree CENTRALIZER PLACEMENT: 1. 5-1/8" x 5-7/8" RH Turbulators -- two per joint on all joints except None on the joint which will be reciprocated across the 7" casing shoe. 2. Estimated total RH Turbulators needed is 40. OTHER CONSIDERATIONS: 1. Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to.pumping job requirement. Displace at 4 - 6 bpm. This job requires that the cement be batch mixed. CEMENT VOLUME: 1. The cement volume is calculated for 30% excess in the openhole and 300' of cement in the the liner lap. SHAR'ED' SE.R'V I,.C.ES ' DR.I- LL :[ N-G "'~:---- Ma rker -I'~1~ n ti tic ~tko'n ...... ' I<KB> · ND"''BK8 ~E~'tN"' INCEN A] KB ........ 0 . 0"."0: '0[0~ B) KOP/BUILO 2.§/100 50~- 500 -O O.OO C) CURVE 2.5/t00' ~86~ t787 375 34.t§ D) END 2,5/100 CURVE 3244 2666 t401 65.0t E) 9-5/8" CASING POINT 3400 2730 1543 . 65,Bt F} DROP 2,0/~Oa lt324 5976 ' 8772 65,8! G] END 2,0/100 DROP 12615"' 6748 "9793' H] IA~GET 13015 7054 tO050 40,00 II 7" CASIflG POINT. 134~ 73§2 10334 . 40,00 J) .ID 13456 7392 't0334 40,00 'MP.J- VERTICAL SECTION VIEN _ Section at: 303.53 TVD $~a]e ' 1 inch O~'SCaIe' l'inch''16OO"leet':'' Dra~n ' · · . . · , - ~--- - WELL - MPJ-19 CPLAN 07) ~'" . ,FENSIB LIT'F PLaN .:~., '.'o '" .,I ,.~ | i O' 50~' DRILL TANGENT TOklcK .. .~ .~ NO'F APPROVED FO~ "" "" ~c,,o. .........................~X~:LU~ ~Um ~- ~-...~..,-,~,-, · ~:. ....... ,~.,,o,.o0.,.~,.,,;. ......... ,. FRM O' ~D TO ~0' ~D _ ~-~- ---~,~,- -m~ ) ~ ~ ) ~oo' ~OG~' ~U~LO 2.~"t~00' OL. ........... ~ FRM D,~' INC TO ~.16", ON AZ ~0~., ' ~ -- ' FRM 600' ~D TO ~78~' _ ~ , . - ~ ~ - 1866' 3~' CURVE 2.6"llD0'DL, -- FRM 34.t5' INC TO 6B.81', F~ AZ TO ~ 303,63, FRM 1787' ~D TO ~866' D E 32~' t t 324' DRILL TANGENT TO DROP POINT. ~ ..... ..... HOLD INC 65.8i',HOLD AZ 303.53*, - "' ~ FRM 2666' ~ TO 6976' "D ' ~ t'3~' 1261~' DROP2.0'i'~0'DL, .OLO mC.4o.,?. ON ~Z ~o~.~' . FRM 6748' ~0 TO 1~'. ~O- ' [] .;- ~ ~ 13015' 1~56' DRILL T~GENT TO TARGET, ........... ~ F~ 70~' ~D TO 7392' ~D ' ' . . - . .. --~ -- - . ~ka/~ ~ ~as Co~s. Co~: ;s[o~ · .'1 ~ ' "-~~ .'~.~-- _~:~ ~_.-. .... ._.~ ,-,-..., .,..~ ~- :~ i-~.~ ~.~..~ ~'E~.EE.. ~E:: ~E'E[' ~:'::: .......... . ........ _ :___ ____...._..__._: .............. ' '"'" '"'""' ' :::::::::::::::::::::::::::::: ~::::~..'~'...~'~... · ....[..:.,......-.'.. ...... .... -.-'- ' ....... '"' · '" .'Z'i:~-:-:: . .. ' i .... f.~: L:-:.' '.:.--kl: '-.-' .... -'-:'-" ...... .~:'-::~~~ ~ ~,' ...... ~ ........ ~.. '~."._:~.~ .: .......... . . : : . ........... ........ I I I' ............. ~. · · ~' .... · ~n~ n~ ' n~ ~c~ ~h~ 440~ ' ~' ~' 0 eoo ~600 e400 3~00 ,~000 4~00 5r, oo ~,~ 7~o0... moo ...... eaOo ........... ......................... S~'ct'~o~ De'pai-turi~ IAnadr~ll (cJ~ ~PJI~7 2.5l),03 lt:~{6 ~ PI · ... '1'1 ;0 0 ') i3-1995 i4:39 FROM ANADRILL TO 5645193 P.06 ? : . i , · ["' ' 'SHARE[~ SERVICES DRIEEiNG ',i',, I ii ii I ii ! · ii i _ _ . , · ii _- ~_ ~ ' I~ ' IIII II i! I I I I ; A~; END ~.0/100 OROP . 1~615 67zl8 9793. 40.00 . BI~ TARCq~T ',30,5~.o~,, ,oo~o: ,,o.oo VERTICAL .SECTION' VlE.W i,, 6): 7'" 6ASIN6 POINT' "$3456 ~392 I0334' 40.00 , , O]'TO 13456 739~ t0334~ 40.00 Sect ion, ~t: 303.53 ii;i I : TVD Sca':le · ~ 'inc'l~ ='200 feet.i · '6ooc' . I Oep Sca:Ie ' 1 incl~ = 200 feet ;' [ ~' ; ' Drawn .... . · 10/13/95' I ' I. .. 6100 .... ~' ' "" '" : I i .. · 8~00 :~ I ... - " '" ' :' ' '~3oo':'i ,,oo: i' N 'NOT A"'r~,¢-, ~'-..' ' - , , - ,- ?-- ,., ~L'...-,~,i'" ,. x ..... 7" ~?cA ., ,~ ~'~ ,~0~:~ ~-~n .... ~'~ ........ ~ ............... ,-. ' I,' ~ · I , :6700.. ~: s : .r I' : :'~': ~ · , ~ . i : ': I "--- ' ~'~°°.,~-~ ... ~:,[ .... ,~ ..... . ........ ,,_ _~:.: ..... '_, .~.~, .......... ;-.-~. ~ ,--% -- · 7000, t . _ . · ~. .... ~- i . ~, ,~,. , t I ~'~_'._,_ _'.... I ~.. ' ; ~ ' :TaOO-- ' - ,' ,,. , = . ~ ' ~, :'' , ~ ,I ~ ... . . ~ , I 7400 : : J -~ ~ ' :~ n ..... . . .. j, I · j~ .': ;'C' . ~i , 7~00-- ... j ~; ..... i -. . r J ~ " ~J:, [ 7~00~ ~ · , . ~ ~: ~ _ ~ ' [' _~. soo0 ~oo ~0o 9300 ~0o ~50~ ~00 9700 9800 ~900 ~0000 ~0100 ~00 ~0300 10400 ~ ' : ,. , ., Section 8epactuce , · '. ii ' i : m ii I · i, a d : ...................... rii : ,ing TO: FROM: DATE: SUBJECT: Bob Crandall, AOGCC Joe Polya, BPX SSD October 13, 1995 Milne Point Well Name and Surface Hole Location Change The MPJ-18 Kuparuk Permit to Drill 95-159 was approved on October 13, 1995. Due to the addition of another well to be drilled on J Pad, this well had to be moved to another conductor and the well name changed. MPJ-18 was planned to drill from: 2262' fsi, 3312' wel, Sec 28, T13N, R10E, UM and will now be renamed MPJ-19 and drilled from the surface location at: 2234' fsi, 3301' wel, Sec 28, T13N, R10E, UM. Thank you, Joe Polya, BPX SSD TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 October 13, 1995 Tim Schofield, Sr. Drlg. Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Well # Company Permit # Surf Loc Btmhole Loc Milne Point Unit MPJ-19 (name change - formerly MPJ-18) BP Exploration (Alaska), Inc. 95-159. 2234'NSL, 3301' WEL, Sec 28, T13N, R10E, UM 2405'NSL, 1422'WEL, Sec 19, T13N, R10E, UM Dear Mr Schofield: Enclosed is the approve~vise~ appli~ati~ for permit to drill the above referenced well. The provisions of the original approved permit dated October 13, 1995, are in effect for this revision. Chairman ~ BY ORDER OF THE COMMISSION /encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl TONY KIVOWLE$, GOVERIVOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 October 13, 1995 Tim Schofield, Senior Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPJ-18 BP Exploration (Alaska), Inc Permit No 95-159 Surf Loc. 2262'NSL, 3312'WEL, Sec. 28, T13N, R10E, UM Btmhole Loc. 2405'NSL, 1422'WEL, Sec. 19, T13N, R10E,-,UM Dear Mr. Schofield: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector 659-3607. /encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill [] Redrill CIIlb. Type of well. Exploratory[] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenCII Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 65 feet Milne Point / Kuparuk River 3. Address 6. Properly Designation P. 0. Box 196612. Anchoracle, Alaska 99519-6612 ADL 025515 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 2262' NSL, 3312' TEL, SEC 28, T13N, RIOE Milne Point Unit At top of productive interval 8. Well number Number 2290' NSL, 1244' TEL, SEC 19, T13N, RIOE MPJ-18 2S100302630-277 At total depth 9. Approximate spud date Amount 2405' NSL, 1422' TEL, SEC 19, T13N, RIOE 10/14/95 $200,000.00 12. Distance to nearest 13. Distance to nearest Well 14. Number of acres in property 15. Proposed depth(uDandTVD) property line ADL 025517 2405 feet No Close Approach feet 2544 13685'MD/7422' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth ~5oo feet Maximum hole angle49.o9 o Maximum surface 4291 psig At total depth (TVD) 6857'/5000 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1#. H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset l (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 2669' 31' 31' 2700' 2505' 526 sx PF 'E', 250 'G', 250 PF 'E' 8-1/2" 7" 26# L-80 Btrc 13115' 30' 30' 13145' 6954' 155 sx c/ass 'G', 159 sx C/ass 'G' 6" 5" 15# L-80 FL4S 685' 13000' 6828' 13685' 7422' 128 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor {~ Surface ~ ~- ~' ~-' ~ Intermediate Production OCT 'l ~ Liner Perforation depth: measured Al~$['~ 0il.& Gas Cons. C0mmJss~ true vertical "Anchorage 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program [] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~¢.-~'T;¢,,,~~ Title Senior Drilling Engineer Date Commission Use Only Permit Number IAPI number Approval date See cover letter ¢,.5"--//.D"-¢ 150- o ~---~ -- 2..- 2_~' 0 F /~ -/~-~,-- ~; ~; for other requirements Conditions of approval Samples required [] Yes ~'No Mud Icg required []Yes ,~ No Hydrogen sulfide measures [] Yes [] No Directional survey required ~ Yes [] NO Required working pressure_f_q, rJS~l~,..~ ~] 2M; 1-13M; ,I]~.5M; 1-110M' 1-115M; Approved by 0avid W Johnston by order of · Commissioner me commission Date/¢ Form 10-401 Rev. 12-1-85 Submit in triplicate Well Name: I MPJ-18 Well Plan Summary Type of Well (producer or injector): [ Kuparuk Producer I Surface Location: Target Location: Bottom Hole Location: 2262 NSL 3312 WEL Sec 28 T13N R10E UM., AK. 2290 NSL 1244 WEL Sec 19 T13N R10E UM., AK. 2405 NSL 1422 WEL Sec 19 T13N R10E UM., AK. [AFE Number: [330168 [ Estimated Start Date: [ 10/14/95 IMD: I13685. I ITVD: I Well Design (conventional, slimhole, etc.): [Rig: [Nabors 22-E [ Operating days to complete: [10 17422' bkb [ I KBE: 165. [ Milne Point Ultra Slimhole-5" liner Formation Markers: Formation Tops MD TVD (bkb) base permafrost 1903 1864 NA 5956 3795 Top of Schrader Bluff Sands (8.3 ppg) OB Seabee Shale 6661 4035 Base of Schrader Bluff Sands (8.3 ppg) HRZ 12559 6482 High Resistivity Zone Top Kup 13108 6925 Kupamk Cap Rock Kuparuk Target Sand 13260 7054 Target Sand (13.6 ppg) Total Depth 13685 7422 Casing/Tubing Program: Hole ~;ize - Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 24" 20" 91.1# H-40 Weld 80 32/32 112/112 12 1/4" 9 5/8" 40# L-80 btrc 2669 31/31 2700/250: 8 1/2" 7" 26# L-80 btrc 13115 30/30 13145/695. 6" 5" 15# L-80 FL4S 685 13000/6828 13685/742 Internal yield pressure of the 7" 26# casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 6857' TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 5000 psi is 4291 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: Open Hole Logs: Surface MWD Directional DSS Intermediate MWD Dir and LWD CDR (GR/RES) Final Insert Bit to TD w/MWD Dir and LWD (GR/RES -- Wireline Triple Combo Back-up). Cased Hole Logs: Mudloggers are NOT required on this well. Mud Program: Special design considerations None- SPUD MUD Surface Mud Properties: ] Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 50 15 8 10 9 8 to to to to to to to 9.0 100 35 15 30 10 15 Intermediate Mud Properties: N/A ] Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Production Mud Properties: ] None- LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 40 10 3 7 8.5 6-8 to tO tO to tO to tO 10.4 50 15 10 20 9.5 4-6 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: [KOP: 11.500' IMaximum Hole Angle: Close Approach Well: 49.09 (No Shut Ins) Disposal: Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. Fluid Handling: MPJ-13 is available for annular injection. Request to AOGCC for Annular Pumping Approval for MPJ-18: 1. Approval is requested for Annular Pumping into the MPJ-18 and MPJ-13 9-5/8" x 7" casing annulii. 2. Aquifers in the Milne Point Unit have been exempted from Class II injection activities by the AOGCC by Aquifer Exemption Order #2 as referenced in Area Injection Order #10. There are no domestic or industrial use water wells located within one mile of the project area. 3. The 9-5/8" casing shoe will be set at 2700' md (2505' tvd) which is a minimum of 500' tvd below the Permafrost and into the Prince Creek formation which has a long established history of annular pumping at Milne Point. 4. The burst rating (80%) for the 9-5/8" 40# L80 casing is 4600 psig while the collapse rating (80%) of the 7" 26# LB0 casing is 4325 psig. The break down pressure of the Seabee formation is 13.5 ppg equivalent mud weight. The Maximum Allowable Surface Pressure while annular pumping is calculated according to the following equation and is 3200 psi for a 10.4 ppg fluid in this well {Assumes worst case in which 7" casing is filled with gas). MASP = 4325 psig - ((fluid density ppg - 1.9) X 0.052 X 9-5/8" Casing Shoe TVD 5. A determination has been made that the pumping operation will not endanger the integrity of the well being drilled by the submission of data to AOGCC on 7/24/95 which demonstrates the confining layers, porosity, and permeability of the injection zone. 6. The cement design for this well ensures that annular pumping into hydrocarbon zones will not occur. AREA WELL PREV VOL PERMITTED PERMITTED INJECTED VOL DATES (BBLS) (BBLS) Milne Point MPJ-13 1220 0 1995 Milne Point MPJ-18 0 0 1995 DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. MPJ-18 Proposed Summary of Operations 1. Drill and Set 20" Conductor. Weld a starting head on conductor. 2. Prepare location for rig move. 3. MIRU Nabors 22E drilling rig. 4. NU and test 20" Diverter system. Build Spud Mud. 5. MU 12-1/4" bit and MWD (Dir), drill surface hole, and run and cement 9-5/8" casing. 6. ND 20" Diverter, NU and Test 13-5/8" BOPE. 7. RIH w/PDC bit on a motor with MWD and CDR/CDN), Test 9-5/8" casing to 3000 psig for 30 minutes, Drill out float equipment and 10 feet of new formation, Perform a FIT -- 12.5ppg. 8. Drill 8.5" hole to +100' tvd above the To Kuparuk Sand, POOH, and LD the PDC bit and 7Stage Motor. 9. Wiper Trip, POOH and LD BHA, Change Top Rams to 7", and Run and Cement 7" casing, Bump the plug, check the floats, and pressure test the casing to 3500 psig for 30 minutes. 10. MU the 6" bit and Sperry LWD (Recorded GR and RES) drill to TD. Wiper Trip to the 7" casing shoe. Drop Rabbit and POOH. 11. RU and Run the 5" liner on 3-1/2" drill pipe. Cement 5" Liner. 12. RIH with 6" bit and scraper to clean off the Top of the 5" liner top packer. POOH. 13. RIH with 4.25" mill and clean out the liner to the landing collar. Test Casing to 4500 psig for 30 minutes. Displace drilling mud with source water with 25 gal/100bbl Corexit and filter. 14. POOH while LD 3-1/2" Drill Pipe -- Freeze Protect Well while POOH. 15. ND BOPE & NU the False Bowl. NU and test the Dry Hole Tree to Prepare Well for Running Completion with 4ES or Polar 1 at a later date. 1 6. RDMO Nabors 22E drilling rig to drill next well. Drilling Hazards and Risks: 1. The Kuparuk A Sand is over pressured to 13.5 ppg and a liner will be set 100' tvd above this sand. 2. Hydrates have not been experienced in the 13 wells that have been drilled on this pad; however, be prepared to follow the Hydrate guidelines as outlined on the pad data sheet. 3. No other drilling hazzards or risks have been identified for this well. CASING SIZE' 9-5/8" MPJ-18 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CIRC. TEMP 50 deg F at 2500' TVDSS. SPACER: 75 bbls fresh water. LEAD CEMENT TYPE: ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX #SACKS: 526 Type E Permafrost YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE: ADDITIVES: 2.0% CaCI2 WEIGHT: 15.8 ppg APPROX #SACKS: 250 FLUID LOSS: 100-150 cc Premium G YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. FREE WATER: 0 TOP JOB CEMENT TYPE: Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx gal/sk APPROX NO SACKS: 250 E MIX WATER: 11.63 CENTRALIZER PLACEMENT: 1. 1 Bowspring centralizer per joint of 9-5/8" casing on bottom 15 joints of casing (15 required). 2. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacedmud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Mix slurry on the fly -- batch mixing is not necessary. CEMENT VOLUME: 1. The Tail Slurry volume is calculated to cover 618' md above the 9-5/8" Casing Shoe with 30% excess. 2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry to 1500' md with 30% excess and from 1500' md to surface with 100% excess. 3. 80'md 9-5/8", 40# capacity for float joints. 4. Top Job Cement Volume is 250 sacks. MPJ-18 Well 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON STAGE I CEMENT JOB ACROSS THE KUPARUK INTERVAL: CIRC. TEMP: SPACER: 140° F BHST 170 deg F at 7040' TVDSS. 20 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1 above current mud weight. CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/s APPROX # SACKS: 155 THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F FLUID LOSS: < 50cc/30 min @ 140° F FREE WATER: 0cc @ 45 degree angle. STAGE II CEMENT JOB ACROSS THE SCHRADER BLUFF SANDS CIRC. TEMP: 60°F BHST 80 deg F at 7040' TVDSS. SPACER: 20bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1 above current mud weight. LEAD CEMENT TYPE: ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX #SACKS: NONE Type E Permafrost YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.2% Halad 344 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk APPROX # SACKS: 159 THICKENING TIME: 4 hours @ 50 FLUID LOSS: 100-150 cc FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7" x 8-1/4" Straight Blade Rigid Centralizers-- one per joint on the bottom 10 joints of 7" (10 total). 3. Run one 7" x 8-1/4"Straight Blade Rigid Centralizer above and below the 7" ES Ceme Total). 2. 7" x 8-1/4"Straight Blade Rigid Centralizers-- two per joint from OB Base Sand to 200' above Sand (26 Total). 3. Run two 7" x 8-1/4"Straight Blade Rigid Centralizer inside the 9-5/8" casing shoe. 4. Total 7" x 8-1/4"Straight Blade Rigid Centralizers needed is 40. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud progra ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to p~ job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. CEMENT VOLUME: 1. Stage 1 cement volume is calculated to cover 1000' md above the 7" casing shoe with 30% E 2. Stage 2 cement volume is calculated to cover from the OB base to 500' above the NA OCT i ~ ~995 oil & 6as Cons, Comm]ssio" Anchorage MPJ-18 5" PRODUCTION CEMENT PROGRAM' CIRC. TEMP' 140°F 7040' TVDSS. LINER HALLIBURTON BHST 170 deg F at SPACER' 20 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 WEIGHT: 15.Sppg YIELD: 1.15 cu ft/sk gal/sk APPROX # SACKS: 128 MIX WATER: 5.0 THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F FLUID LOSS: < 50cc/30 min @ 140° F FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 5-1/8" x 5-7/8" RH Turbulators -- two per joint on all joints except None on the joint which will be reciprocated across the 7" casing shoe. 2. Estimated total RH Turbulators needed is 40. OTHER CONSIDERATIONS: 1. Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 4 - 6 bpm. This job requires that the cement be batch mixed. CEMENT VOLUME: · The cement volume is calculated for 30% excess in the openhole and 300' of cement in the the liner lap. <KS> !, SHARED S'ERVICES DRIL'LTNG iiii i iiiiii i i Marker Irlentkfication A) KB B) KOP/BUILD 2.5/100 C) CURVE 2.5/100 D) END 2.5/100 CURVE E) DROP 1.5/~00 F) TARGET G) ID MD BKB SECIN INCLN 0 0 0 '0.00 800 800 -0 0.00 1200 1198 29 10.00 3671 3016 1518 70.07 ~0589 5373 B022 70,07 ~3260 7054 10028 30.OD 13685 7422 10240 30.00 m im i iii iml m VERTICAL SECTION VIEW Section at: 302.84 fVD Scale.' I inch : ]600 feet Dep Sca]e,' 1 inch = 1600 feet Drawn ' ]0/10/95 8000 0 800 t800 2400 3200 4000 4800. 5600 6400 7200 8000 8800 9800 '10400 ! 1200 12000 12800 13600 Section Departure i i mm ilml im I i mlmlmml i i iN mm Im 'odgsDP4 2.5b.02 3:33 PM P) ' "SHARED SERV'i'CES ' DRILLIN6 ,, i : ISCALE ....... : ~. inch : ~200 feet )-- '. - ~- IDRAWN ....... : ~.0/10/95 I , I ' ) ....... ~.~, .. Marker Identif ,cation t40 N/S E/W A) KB O 0 0 ~ ?00 FT T,,RGET RA[ IUS B) KOP/BUILD 2.5/~00 BOO' 0 0 C) CURVE 2.5/100 ~200 0 35 )--~ ~ .... ~ ..... D) END 2.5/300 CURVE 367~ 699 J356 E) DROP ~.5/~00 $0589 4225 6820 F) TARGEI ~3260 5313 8506 G) TO S3685 5428 8684 ; ~ A~:ADRIL . AKA -DPC ,_~ FFA~IBI~ITY )LA q ~ ._ ~OTAPPROVi~D R)R . EXECJTI()N , c~. ' 'I , O, m MPJ-95D (P4) -~"' PLAN VlE~ CLOSURE ' 102.4t feet at Azimuth 302.0~1 '0200 9600 9000 8400 7800 7200 6600 6000. 5400 4800 4200 3600 3000 2400 1800 1200 600 0 600 <- WEST ' EAST -> MI~Jg5DP4 2.~.02 3:42 Pti P) _m, WELL PERMIT CHECKLIST FIELO ~ POOL. CO~NY ~/~ WELL NAM~ GEOL AREA UNIT# PROGRAM: exp [] dev/~ redrll [] aery [] ON/OFF SHORE ~ ~) ADMINISTRATION ENGINEERING 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary. . 6. Well located proper distance from other wells ..... ~ 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... 1 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval.., 13. Can permit be approved before 15-day wait ....... APPR 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ ~-~ N 16. CMT vol adequate to circulate on conductor & surf csg..--~ N 17. CMT vol adequate to tie-in long string to surf csg . . . 18. CST will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndrnnnt been approved. 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate ........... Y N 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to .~O~-~ pslg.~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y//~ 32. Se±stoic analysis 9f shallow gas zones .......... 33. Seabed condition survey (if off-shore) ........ /Y N 34. Contact name/phone for weekly progress reports . . .~/ . Y N [exploratory only] GEOLOGY: ENGINEERING: CO~ON: ~Pc~ BEW owJ~.f ~ Comments/Instructions: TAB '~W/jo - A:~FORMS~cheklist rev 03/94 WELL PERMIT CHECKLIST COMPANY ~ WELL NAME ./~/~ 7~ ./~ PROGRAM: exp n dev~redrll ~1 serv ri ADMINISTRATION ENGINEERING 5. 10. 11. 12. 13. 2. Lease number appropriate ................ 3. Unique well na~e and nu/nber ............... 4. Well located in a defined pool. Well located proper distance from drlg unit boundary. . Well located proper distance from other wells ...... Sufficient acreage available in drilling unit ..... If deviated, is wellbore plat included ........ Operator only affected party .............. Operator has appropriate bond in force ......... Permit can be issued without conservation order .... Permit can be issued without administrative approval. . Can permit be approved before 15-day wait ....... 14. Conductor string provided ............... 15. Surface casing protects all known USDWs' . ....... 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved.~vY-~-~ ,x~/~ / 22. Adequate wellbore separation proposed .......... ~ 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic& equip list adequate. 25. BOPEs adequate ..................... 26. BOPE press rating adequate; test to ~~ psig.~ N __/L_ 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable , .... ....... ~ GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N~ 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis 9f shallow gas zones .......... Y 33. Seabed condition survey (if off-shore) ......... ~ N 34. Contact name/phone for weekly progress reports /. Y N [exploratory only] ' ' ' ~ GEOLOGY: ENGINEERING: COMMISSION: BEW DWJ JDH ~"'~' RAD TAB Comments/Instructions: Z /' HOW/jo - A:'d::ORMS\cheklist rev 03194 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. RECEIVED DEC 1 5 1995 * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER COMPANY NAME : B. P. EXPLORATION WELL NAME : MPJ-16 FIELD NAME : MILNE POINT BOROUGH ' NORTH SLOPE STATE · ALASKA API NUMBER : 50-029-22615-00 REFERENCE NO : 95386 LIS Tape Ver=£ication Listing Schlumberger Alaska Computing Center 12-DEC-1996 08:z5 PAGE: *~** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/12/12 ORIGIN : FLIC REEL NAME : 95386 CONTINUATION # PREVIOUS REEL : COf~ENT : BP EXPLORATION, MILNE POINT MPJ-16, API #50-103-20230-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/12/12 ORIGIN ' FLIC TAPE NAME : 95386 CONTINUATION # : 1 PREVIOUS TAPE : COfZfl~_al~f : BP EXPLORATION, MILNE POINT MPJ-16, API #50-103-20230-00 TAPE HEADER MILNEPOINT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB ~ER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL : FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING MPJ-16 500292261500 B. P. EXPLORATION SCHLUMBERGER WELL SERVICES 8-DEC-95 BIT RUN1 ......... 95386 ST. AMOUR MOUNTJOY BIT RUN 2 BIT RUN 3 28 13N iOE 2317 3336 65. O0 65. O0 35. O0 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8. 500 9. 625 3133 . 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-DEC-1996 08:25 3RD STRING PRODUCTION STRING Well drilled 03-NOV through lO-NOV-95 with CDR/CDN. All data was collected in a single bit run. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION : O01CO1 DATE : 96/12/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 1 EDITED MERGEDMWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUNMARY LDWG TOOL CODE $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 12212.0 2997.0 BASELINE DEPTH 88888 0 11975 5 11958 5 11882 0 11874 5 11811 5 11780 0 11752 0 11659 0 11650.0 11528.0 11495.5 11459.5 11450.0 11374.5 11364.5 11217.0 11192.5 11182.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... 88873.5 11961.0 11944.0 11867.5 11859.5 11796.5 11765.0 11736.0 11643 11633 11511 11478 11442 11433 11357 11347 11199 11175 11164 .0 .5 5 5 0 0 0 0 5 0 0 LIS Tape Verl£ication Listing Schlumberger Alaska Computing Center 11149.0 10969.5 10947.5 10926.5 10748.0 10695.5 10610.5 10598.0 10568.0 10525.0 10408.0 10283.0 10061.0 9939.5 9625.0 9522.5 6377.0 6372.5 6346.5 6318.5 6256.0 6247.0 6104.0 6085.5 6072.5 6056.0 6000 0 5995 0 5989 0 5968 5 5896 5 5891 5 5868.5 5834.0 5786.0 5727.0 5716.5 5646.5 5631.0 5616.5 5608.5 5553.0 5514.0 5491.5 5478.5 5446.0 5431.0 5422.0 5418.5 5406.0 5351.5 5324.5 5313.0 52 65.0 5249.0 11131.0 10952.0 10929.5 10909.0 10730.0 10677.5 10591.0 10580.0 10548.0 10506.0 10389 0 10264 0 10045 5 9922 5 9607 5 9506 5 6357 5 6354 0 6327.5 6299.0 6237.5 6227.5 6084.0 6066.0 6052.0 6036.5 5978.5 5974.0 5968.0 5949.5 5875.5 5870.0 5847 5 5813 0 5765 0 5705 0 5695 0 5625 0 5610 0 5595 5 5586.5 5532.5 5492.0 5469.5 5457.5 5424.5 5410.0 5400.0 5396.0 5384.0 5329.5 5302.0 5293.0 5244.0 5227.5 12-DEC-1996 08:z5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 5237.5 5207.5 5179.0 5135.0 5122.0 5071.5 5063.5 5038.5 5015.0 4935.5 4898.5 4894.0 4874.0 4784.0 4732.0 4702.0 4679.5 4 652.5 4615.0 4569.0 4540.0 4519.5 4507.5 4446.0 4432.0 4413.0 4393.0 4318.5 4295.5 4270.5 4237.5 4216.0 4160.0 4137.5 4018.5 3917.0 3890.0 3873.0 3856.5 3835 5 3780 5 3758 5 3 655 5 3625 5 3594 5 3559 0 3514 5 3494 5 3457 0 3431 5 3417 0 3404 0 3390 5 3381 5 3359 5 5216.5 5185.5 5157.5 5113.0 5099.0 5050.0 5043.0 5017.5 4993.5 4915. 0 4877.0 4872.0 4852.0 4762.5 4711.0 4679.5 4656.0 4629.5 4593.5 4547.0 4519.5 4496.0 4484.5 4423.0 4408.5 4391.0 4371.0 4296.5 4273.0 4248.5 4215.5 4194.5 4137.5 4115.0 3995.5 3896.0 3868.0 3850.0 3835.5 3813.5 3757.5 3736.0 3633.5 3604.0 3573.5 3537.0 3492.5 3473.0 3434.5 3408.5 3396.5 3382.5 3366.0 3358.5 3336.0 12-DEC-1996 08:Z5 PAGE: LIS Tape Verl£ication Listing Schlumberger Alaska Computing Center 12-DEC-1996 08:z3 PAGE: 3316.0 3292.5 3284.0 3240.0 100.0 $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: 3292.5 3270.5 3261.5 3217.5 77.5 BIT RUN NO. MERGE TOP MERGE BASE The depth adjustments sho~n above reflect the MWD GR to the GR logged by Atlas. Ail other MWD curves were carried with the GR. This file also contains the Very Enhanced QRO resisitivity with 2' average that was reprocessed at GeoQuest. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 60 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 17 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NTJMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630353 O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD Otff4M630353 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-DEC-1996 08:zm PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE C~SS MOD NUMB SAMP ELEM CODE (HEX) RP MWD OH~M 630353 O0 000 O0 0 1 1 1 4 68 VRA MWD OI~ff4630353 O0 000 O0 0 1 1 1 4 68 VRP MWD OH~k4 630353 O0 000 O0 0 1 1 1 4 68 DER MWD OH~4 630353 O0 000 O0 0 1 1 1 4 68 ROP MWD FPHR 630353 O0 000 O0 0 1 1 1 4 68 FET MWD HR 630353 O0 000 O0 0 1 1 1 4 68 GR MWD GAPI 630353 O0 000 O0 0 1 1 1 4 68 RHOBMWD G/C3 630353 O0 000 O0 0 1 1 1 4 68 DRHOMWD G/C3 630353 O0 000 O0 0 1 1 1 4 68 PEF MWD BN/E 630353 O0 000 O0 0 1 1 1 4 68 CAIAVMWD IN 630353 O0 000 O0 0 1 1 1 4 68 NPHIMWD PU-S 630353 O0 000 O0 0 1 1 1 4 68 GRCH GRCH GAPI 630353 O0 000 O0 0 1 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 12198.000 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD 142.399 FET.MWD GR.MWD -999.250 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALN. MWD -999.250 NPHI.I~WD -999.250 GRCH. GRCH -999.250 DEPT. 12000.000 RA.MWD 2.528 RP.MWD 2.604 VRA.MWD VRP.MWD 2.564 DER.MWD 2.575 ROP.MWD 74.288 FET.MWD GR.MWD 93.171 RHOB.MWD 2.501 DRHO.MWD 0.044 PEF.MWD CALN.MWD 8.841 NPHI.MWD 32.600 GRCH. GRCH -999.250 DEPT. 9000.000 RA.~CD 3.101 RP.MWD 3.270 VRA.~CD VRP.MWD 3.234 DER.MWD 3.207 ROP.MWD 154.594 FET.MWD GR.MWD 88.064 RHOB.MWD 2.434 DRHO.MWD 0.032 PEF.MWD CALN.MWD 8.667 NPHI.MWD 34.388 GRCH. GRCH -999.250 DEPT. 6000.000 RA.MWD 4.317 RP.MWD 4.087 VRA.MWD VRP.MWD 4.039 DER.MWD 4.156 ROP.MWD 238.568 FET.MWD GR.MWD 78.367 RHOB.MWD 2.372 DRHO.MWD 0.057 PEF.MWD CAL1V. MWD 9.216 NPHI.MWD 334355 GRCH. GRCH 58.220 DEPT. 3000.000 RA.~CD -999.250 RP.MWD -999.250 VRA.MWD VRP.MWD 1000.000 DER.MWD -999.250 ROP.MWD -999.250 FET.MWD GR.MWD -999.250 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALN. MWD -999.250 NPHI.MWD 40.800 GRCH. GRCH -999.250 DEPT. 2996.500 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.~CD -999.250 FET.MWD GR.MWD -999.250 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CAIAV.MWD -999.250 NPHI.MWD 55.800 GRCH. GRCH -999.250 -999.250 -999.250 -999.250 2. 584 O. 744 3. 252 3.088 0.318 3.089 4.184 2.700 2.908 1000.000 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-DEC-1996 08:25 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 96/12/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION . O01CO1 DATE : 96/12/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ~ER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: O . 5000 FILE SUMM~ Y VENDOR TOOL CODE START DEPTH STOP DEPTH 12212.0 2997.0 LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) '. BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GARE~A RAY GR GARk4A RAY $ 10 -NOV- 95 FAST 4.0C MEMORY 12212.0 3070.0 12212.0 75 40.5 63.2 TOOL NUMBER ........... RGS022 NDS022 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12-DEC-1996 08:25 PAGE: BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 8.500 3133.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.20 MUD VISCOSITY (S) : 4 6.0 MUD PH: MUD CHLORIDES (PPM) : 600 FLUID LOSS (C3): 4.0 RESISTIVITY (OH~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 2.230 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 2.110 MUD CAKE AT (MT): 0.000 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): O. 5 EWR FREQUENCY (HZ): 20000 REMARKS: ************ RUN 1 ************* DRILLED INTERVAL 3133 ' - 12212 ' MAXIMUM DEV. 63.15 @ 5766', 40.5 @ TD RES TO BIT: 52.60'; GR TO BIT: 63.02' NEUT TO BIT: 114.55'; DENS TO BIT: 107.61' TD WELL @ 11:00 8-NOV-95 DATA FROM DOWNHOLE MEMORY, V4. OC SOFTWARE $ LIS FORMAT DATA 67.0 62.0 0.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT LIS Tape Verl.ication Listing Schlumberger Alaska Computing Center 12-DEC-1996 08:25 PAGE: TYPE REPR CODE VALUE 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630353 O0 000 O0 0 2 1 1 4 68 0000000000 RA LW1 OH~ff4630353 O0 000 O0 0 2 1 1 4 68 0000000000 RP LW1 OH~iM 630353 O0 000 O0 0 2 1 1 4 68 0000000000 VRA LW1 OH~fi~630353 O0 000 O0 0 2 1 1 4 68 0000000000 VRP LW1 OH~4~ 630353 O0 000 O0 0 2 1 1 4 68 0000000000 DER LW1 OH~4~ 630353 O0 000 O0 0 2 1 1 4 68 0000000000 ROP LW1 FPHR 630353 O0 000 O0 0 2 1 1 4 68 0000000000 FET LW1 HR 630353 O0 000 O0 0 2 1 1 4 68 0000000000 GR LW1 GAPI 630353 O0 000 O0 0 2 1 1 4 68 0000000000 RHOB LWl G/C3 630353 O0 000 O0 0 2 1 1 4 68 0000000000 DRHO LW1 G/C3 630353 O0 000 O0 0 2 1 1 4 68 0000000000 PEF LW1 BN/E 630353 O0 000 O0 0 2 1 1 4 68 0000000000 CAI~¥ LW1 IN 630353 O0 000 O0 0 2 i 1 4 68 0000000000 NPHI LW1 PU-S 630353 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 12212.500 RA.LW1 -999.250 RP.LW1 -999.250 VRA.LW1 VRP. LW1 -999. 250 DER. LW1 -999. 250 ROP. LW1 142. 399 FET. LW1 GR. LW1 -999. 250 RHOB. LW1 -999. 250 DRHO. LW1 -999. 250 PEF. LW1 CALN. LW1 -999.250 NPHI.LW1 -999.250 DEPT. 12000.000 RA.LW1 2.343 RP.LW1 2.203 VRA.LW1 VRP. LW1 2. 564 DER. LW1 2. 252 ROP. LW1 71.636 FET. LW1 GR.LW1 100. 701 RHOB.LW1 2.529 DRHO.LW1 O. 060 PEF. LW1 CALN. LW1 8.913 NPHI.LW1 29.300 DEPT. 9000.000 RA.LW1 2.804 RP.LW1 2.945 VRA.LW1 VRP. LW1 3 . 234 DER. LW1 2. 891 ROP. LW1 95. 533 FET. LW1 GR.LW1 90.563 RHOB.LW1 2.388 DRHO.LW1 0.112 PEF. LW1 CALN. LW1 8.519 NPHI.LW1 32.300 DEPT. 6000.000 RA.LW1 7.205 RP.LW1 10.858 VRA.LW1 VRP.LW1 4.039 DER.LW1 9.602 ROP.LW1 63.122 FET. LW1 GR.LW1 41.546 RHOB.LW1 2. 472 DRHO.LW1 0.035 PEF. LW1 CALN. LW1 8. 909 NPHI.LW1 25. 300 -999.250 -999.250 -999.250 2.584 O. 822 3. 057 3.088 0.323 2.721 4.184 O. 275 3. 375 LIS Tape Verl£ication Listing Schlumberger Alaska Computing Center 12-DEC-1996 08:25 PAGE: 10 DEPT. 2997.000 RA.LW1 -999.250 RP.LW1 -999.250 VRA.LW1 VRP.LW1 1000. 000 DER.LW1 -999.250 ROP.LW1 -999.250 FET.LW1 GR.LW1 -999.250 RHOB.LW1 -999.250 DRHO.LW1 -999.250 PEF.LW1 CALN. LW1 -999. 250 NPHI. LW1 -999. 250 1000.000 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/12/12 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 96/12/12 ORIGIN : FLIC TAPE NAME : 95386 CONTINUATION # : 1 PREVIOUS TAPE : CO~IENT : BP EXPLORATION, MILNE POINT MPJ-16, API #50-103-20230-00 **** REEL TRAILER **** SERVICE NAi~E : EDIT DATE : 96/12/12 ORIGIN : FLIC REEL NAME : 95386 CONTINUATION # : PREVIOUS REEL : COGENT · BP EXPLORATION, MILNE POINT MPJ-16, API #50-103-20230-00 ALASKA COMPUTING CENTER SCHLUMBERGER COMPANY NAME : B.P. EXPLORATION WELL NAME : MPJ-19 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22607-00 REFERENCE NO : 95363 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-DEC-1995 11:40 · *,, REEL HEADER *~, SERVICE NAME : EDIT DATE : 95/12/21 ORIGIN : FLI¢ REEL NAME : 95363 CONTINUATION # : PREVIOUS REEL : COMMENT : B.P. EXPLORATION, MILNE POINT MPJ-19, API #50-029-22607-00 **** TAPE HEADER SERVICE NAME : EDIT DATE : 95/~2/2[ ORIGIN : FLIC TAPE NAME : 95363 CONTINUATION ~ : 1 PREVIOUS TAPE : COMMENT : B.P. EXPLORATION, MILNE POINT MPJ-I9, API #50-029-22607-00 TAPE HEADER MILNE POINT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPJ-19 509292260700 B.P. EXPLORATION SCHLUMBERGER WELL SERVICES 21-DEC-95 BIT RUN I BIT RUN 2 BIT RUN 3 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 9) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 95363 ST.AMOUR 28 3.3N 'igE 2234 3391 64.59 64.59 35.69 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 8.509 9.625 3390.0 PAGE: LIS Tape Veri~icatien Listing Schlumberger Alaska Computing Center 21-DEC-1995 11:40 3RD STRING PRODUCTION STRING REMARKS: Well drilled 18-OCT through 25-0CT-95 with CDR/CDN. All data was collected in a single bit run. MAD data was collected after drilling from 5830' to 5221' $ $ **** FILE HEADER ***~ FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : g5/12/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : PAGE: FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH MWD 13087.0 3315.0 $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH MWD $ MERGED DATA SOURCE LDWG TOOL CODE BIT RUN NO. MERGE TOP MERGE BASE REMARKS: No depth adjustments were made as per G. Piekenprock. This file also contains the Very Enhanced QRO resisitivit¥ with 2' average that was reprocessed at GeoQuest. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-DEC-1995 11:40 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 2 66 0 3 73 56 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 12 68 14 65 FT 15 66 68 16 66 I SET TYPE - CHAN ** PAGE: NAME SERV UNIT SERVICE aPI AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630352 00 000 00 0 I I 1 4 68 0000000000 RA MWD OHMM 630352 00 000 00 0 1 1 1 4 68 0000000000 RP MWD OHMM 630352 00 000 00 0 1 1 1 4 68 0000000000 VRA MWD OHMM 630352 00 000 00 0 1 1 1 4 68 0000000000 VRP MWD OHMM 630352 00 000 00 0 I I 1 4 68 0000000000 DER LWD OHMM 630352 00 000 00 0 1 1 1 4 68 0000000000 ROP LWD FPHR 630352 00 000 90 9 1 1 1 4 68 0000090000 GR MWD GAPI 630352 00 000 09 0 1 1 1 4 68 0909090000 RHOB MWD G/C3 630352 90 000 00 0 1 I 1 4 68 9090900000 DRHO MWD G/C3 639352 90 000 00 0 1 1 1 4 68 0000000000 PEF MWD BN/E 630352 00 000 90 0 1 1 1 4 68 0900900090 CALN MWD IN 630352 09 999 99 9 1 1 1 4 68 0000009000 NPHI LWD PU-S 630352 90 000 90 9 1 1 1 4 68 0000990090 ** DATA ** DEPT. 13086.500 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD VRP.MWD -999.250 DER.LWD -999.250 ROP.LWD 7.992 FET.LWD GR.MWD -999.250 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALN.MWD -999.250 NPHI.LWD -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-DEC-1995 11:40 DEPT. 3307.000 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD VRP.MWD -999.250 DER.LWD -999.250 ROP.LWD -999.250 FET.LWD GR.MWD -999.250 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALN.MWD -999.250 NPHI.LWD 52.100 PAGE: -999.250 -999.250 -999.250 ** END OF DATA ***, FILE TRAILER FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 95/12/2! MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : eO[CO[ DATE : 95/12/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Non-depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: e.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH MAD $ MERGED DATA SOURCE LDWG TOOL CODE 5830.~ 5221.e MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE $ REMARKS: This file contains the MAD data collected 110 hours after drilling from 5830' to 5221'. No depth shifts were made as per G, Piekenprock. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-DEC-1995 11:40 PAGE: DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB *~ TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 52 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 12 68 13 66 0 14 65 FT 0 66 1 SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630352 00 000 00 0 2 1 1 4 68 0000000000 RA MAD OHMM 630352 00 000 00 0 2 1 1 4 68 0000000000 RP MAD OHMM 630352 00 00~ 00 ~ 2 ~ 1 4 68 00~0000000 vra MAD OHMM 630352 00 000 ~0 0 2 1 1 4 68 00~00~0000 VRP MAD OHMM 630352 00 000 00 0 2 ! ~ 4 68 0000000000 DER MAD OHMM 630352 00 000 00 0 2 ~ 1 4 68 0000000000 ROP MAD FPHR 630352 00 000 00 0 2 1 1 4 68 0000000000 GR MAD GAPI 630352 00 000 00 0 2 ! ~ 4 68 0~00000000 RHOB MAD ~/C3 630352 00 000 00 0 2 ~ ~ 4 68 0000000000 DRHO MAD G/C3 630352 00 000 00 0 2 ! 1 4 68 000~000000 PEF MAD BN/E 630352 00 ~00 ~0 e 2 ! Z 4 68 0e00~0000~ CALN MAD ZN 630352 00 00e 00 0 2 1 1 4 68 0e0~000000 NPH~ MA1 PU-S 630352 00 000 00 0 2 1 ~ 4 68 0000~000~0 DATA ** DEPT. 5830.509 RA.MAD -999.259 RP.MAD VRP.MAD -999.259 DER.MAD -999.259 ROP.MAD RHOB.MAD -999.259 DRHO.MAD -999.259 PEF.MAD NPHI.MA1 -999.259 -999.259 VRA.MAD 393.289 GR.MAD -999.259 CALN.MAD -999.259 -999.259 -999.259 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-DEC-1995 11:40 PAGE: DEPT. 5221.000 RA.MAD -999.250 RP.MAD -999.250 VRP.MAD -999.250 DER.MAD -999.250 ROP.MAD -999.250 RHOB.MAD -999.250 DRHO.MAD -999.250 PEF.MAD -999.250 NPHI.MA1 39.100 VRA.MAD GR.MAD CALN.MAD -999.250 -999.250 -999.250 END OF DATA **** FILE TRAILER FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 9s/i2/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT SERVICE : FLIC VERSION : 0OlCOl DATE : 95/12/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED MAD PASSES Non-depth shifted and clipped curves; for each pass of each run in separate files. MAD RUN NUMBER: MAD PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH MAD 5830.0 5221.0 $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH MAD $ REMARKS: This file contains the MAD data collected 110 hours LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-DEC-1995 11:40 after drilling from 5830' to 5221' were made as per G, Piekenprock. $ LIS FORMAT DATA · No depth shifts PAGE: DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 52 4 66 5 66 6 73 7 65 8 68 0.5 9 65 fT 11 66 19 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 639352 99 999 99 9 3 1 1 4 68 9999999999 RA MAD OHMM 639352 99 999 99 9 3 1 1 4 68 9999999999 RP MAD OHMM 639352 99 999 99 9 3 1 1 4 68 9999999999 VRA MAD OHMM 639352 99 999 99 9 3 1 1 4 68 9999999999 VRP MAD OHMM 639352 99 999 99 9 3 1 1 4 68 9999999999 DER MAD OHMM 639352 99 990 99 9 3 1 1 4 68 9999999999 ROP MAD FPHR 639352 99 999 99 9 3 1 1 4 68 9999999999 GR MAD GAPI 639352 99 999 99 9 3 1 1 4 68 9999999999 RHOB MAD G/C3 639352 99 999 99 9 3 1 1 4 68 9999999999 DRHO MAD G/C3 639352 99 999 99 9 3 1 1 4 68 9999999999 PEF MAD BN/E 639352 99 999 99 9 3 1 1 4 68 9999999999 CALN MAD IN 639352 99 999 99 9 3 1 1 4 68 9999999999 NPHI MA1 PU-S 639352 99 999 99 9 3 1 1 4 68 9999090999 LIS Tape Verifica~ion Listing Schlumberger Alaska Computing Center ** DATA 21-DEC-1995 11:40 DEPT. 5830.500 RA.MAD -999.250 RP.MAD -999.250 VRP.MAD -999.250 DER.MAD -999.250 ROP.MAD 393.280 RHOB.MAD -999.250 DRHO.MAD -999.250 PEF.MAD -999.250 NPHI.MA1 -999.250 VRA.MAD GR.MAD CALN.MAD PAGE: -999.250 -999.250 -999.250 END OF DATA **** FILE TRAILER FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 001COI DATE : 95/12/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : 001C01 DATE : 95/12/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 13087.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): 3307.0 25-0CT-95 FAST2.5 4.0C MEMORY 13087.¢ 3357.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 2i-DEC-1995 i1:40 BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 15~87.0 70 42.2 67.9 TOOL NUMBER CDR RESISTIVITY CDN DENSITY/NEUTRON $ RGS022 NDS022 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): 8.500 $390.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): LSND 10.40 30~ 2. 890 2.560 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 0.5 20000 REMARKS: ,~********** RUN 1 DRILLED INTERVAL 3421' - 13087' HOLE ANGLE AT TD = 42.18 DEG ~ RES TO BIT: 53.77'; GR TO BIT: NEUT TO BIT: ii5.73'; DENS TO BIT: i08.79' TD WELL ~ ~2:00 25-0CT-95 MAD PASS UP DATA COLLECTED 5833'-5335~ CDN TOOL FAILED 5745'-5875~ 7278'-8~53' $ LIS FORMAT DATA 73.0 69.0 PAGE: LIS Tape Veri,~ication Listing Schlumberger Alaska Computing Center 21-DEC-1995 11:40 ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPe REPR CODE VALUE 1 66 2 66 0 3 73 56 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 I SET TYPE - CHAN ** PAGE: 10 NAME SERV UNIT SERVICE API API API aPI FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630352 ~0 000 00 0 4 1 1 4 68 0000000000 RA MW1 OHMM 630352 00 000 00 0 4 1 1 4 68 000eeoe000 RP MW1 OHMM 630352 00 000 00 0 4 I 1 4 68 0000000000 VRA MW1 OHMM 630352 00 000 00 0 4 1 1 4 68 0000000000 VRP MW1 OHMM 630352 00 000 00 0 4 1 1 4 68 0000000000 DER MW1 OHMM 630352 00 000 00 0 4 1 1 4 68 0000000000 ROP MW1 FPHR 630352 ~0 000 00 0 4 1 1 4 68 0000000000 FET MW1 HR 630352 00 000 ~0 0 4 1 1 4 68 0000000000 GR MW1 GAPI 630352 00 000 00 0 4 1 1 4 68 0000000000 RHOB MW1 G/C3 630352 00 000 00 0 4 1 1 4 68 0000000000 DRHO MW1 G/C3 630352 00 000 00 0 4 1 1 4 68 0000000000 PEF MW1 BN/E 630352 00 000 00 0 4 1 1 4 68 0000000000 CALN MW1 IN 630352 00 000 00 0 4 1 1 4 68 0000000000 NPHI MW1 PU-S 630352 00 000 00 0 4 1 1 4 68 00eooooooe DATA DEPT. 13086.500 RA.MW1 -999.250 RP.MW1 -999.250 VRA.MW1 VRP.MWl -999.250 DER.MW1 -999.250 ROP.MW1 7.992 FET.MWl GR.MWl -999.250 RHOB.MW1 -999.250 DRHO.MWl -999.250 PEF.MW1 CALN.MWl -999.250 NPHI.MW1 -999.250 -999.250 -999.250 -999.250 LIS Tape Ver|,ficatipn Listing Schlumberger Alaska Computing Center DEPT. 3307.000 RA.MW1 VRP.MW1 -999.250 DER.MW1 GE.MW1 -999.25~ RHOB.MW1 CALN.MW1 -999.250 NPHI.MW1 END OF DATA 21-DEC-1995 11:40 -999.250 RP.MWl -999.250 ROP.MWl -999.250 DRHO.MWl 52.100 -999.250 VRA.MW1 -999.250 FET.MW1 -999.250 PEF.MW1 PAGE: 11 -999.250 -999.250 -999.250 **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : 001C01 DATE : 95/12/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER FILE NAME : EDIT SERVICE : FLIC VERSION : 001C01 DATE : 95/12/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW MAD Curves and log header data for each pass of each run in separate files. MAD RUN NUMBER: 1 MAD Pass NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MAD 5830.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): 5221.0 25-0CT-95 FAST2.5 4.0C MEMORY 13087.0 3357.0 13087.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 21-DEC-1995 1~:40 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 70 62.8 67.9 TOOL NUMBER CDR RESISTIVITY CDN DENSITY/NEUTRON RGS022 NDS022 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): 8.500 3390.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): LSND 10.40 300 2.890 2.560 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 0.5 20000 REMARKS: ************ RUN DRILLED INTERVAL 3421~ - 13087~ HOLE ANGLE AT TD = 42.~8 DEG ~ 13057~ RES TO BIT: 53.77~; GR TO BIT: 64.19~ NEUT TO BIT: 115.73~; DENS TO BIT: 108.79~ TD WELL ~ 12:~0 25-0CT-95 MAD PASS UP DATA COLLECTED 5833~-5335~ CDN TOOL FAILED 5745~-5875~ 7278~-8153~ $ LIS FORMAT DATA 73.0 69.0 PAGE: 12 LIS Tape Veri£icatipn Listing Schlumberger Alaska Computing Center 21-DEC-1995 11:40 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ~* TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 52 4 66 5 66 6 73 7 $ 68 0.5 9 65 FT 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 SET TYPE - CHAN ** PAGE: 13 NAME SERV UNIT SERVICE API API APl API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630352 00 000 00 0 5 I I 4 68 0000000000 RA MA1 OHMM 630352 00 000 00 0 5 1 1 4 68 00000000~0 RP MA1 OHMM 630352 00 000 00 0 5 I 1 4 68 0000000000 VRA MA1 OHMM 630352 00 000 00 0 5 1 I 4 68 0000000000 VRP MA1 OHMM 630352 00 000 00 0 5 1 I 4 68 0000000000 DER MA1 OHMM 630352 00 000 00 0 5 1 1 4 68 0000000000 ROP MA1 FPHR 630352 00 000 00 0 5 1 I 4 68 0000000000 GR MA1 GAPI 630352 00 000 00 0 5 1 1 4 68 0000000000 RHOB MA1 G/C3 630352 00 000 00 0 5 I 1 4 68 0000000000 DRHO MA1 G/C3 630352 00 000 00 0 5 1 I 4 68 0000000000 PEF MA1 BN/E 630352 00 000 00 0 5 1 I 4 68 0000000099 CALN MA1 IN 639352 99 999 99 9 5 1 1 4 68 9999999999 NPHI MA1 PU-S 639352 99 999 99 9 5 I 1 4 68 9999999999 DATA DEPT. 5839.599 RA.MA1 -999.259 RP.MA1 -999.259 VRA.MA1 VRP.MA1 -999.259 DER.MA1 -999.250 ROP.MA1 393.289 GR.MA1 RHOB.MA1 -999.259 DRHO.MA1 -999.259 PEF.MA1 -999.259 CALN.MA1 NPHI.MA1 -999.250 -999.259 -999.259 -999.259 LiS Tape Verifi=atipn Listing Schlumberger Alaska CompuEing CenSer 21-DEC-1995 11:40 PAGE: 14 DEPT. 5221.000 RA.MA1 -999.250 RP.MA1 VRP.MA1 -999.250 DER.MA1 -999.250 ROP.MA1 RHOB.MA1 -999.250 DRHO.MA1 -999.250 PEF.MA1 NPHI.MA1 39.100 -999.250 VRA.MA1 -999.250 GR.MA1 -999.250 CALN.MA1 -999.250 -999.250 -999.250 ** END OF DATA **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : OO1CO1 DATE : 95/12/21 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER SERVICE NAME : EDIT DATE : 95/12/21 ORIGIN : FLIC TAPE NAME : 95363 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : B.P. EXPLORATION, MILNE POINT MPJ-19, API ~50-029-22607-00 **** REEL TRAILER SERVICE NAME : EDIT DATE : 95/12/21 ORIGIN : FLIC REEL NAME : 95363 CONTINUATION ~ : PREVIOUS REEL : COMMENT : B.P. EXPLORATION, MILNE POINT MPJ-19, API #50-029-22607-00